exchanger

Abstract The deep carbonate reservoir formation on this field has proven to be an extreme High-temperature (HT) environment for downhole equipment. While drilling the 5000 - 6500 ft 5-7/8" slim long laterals across this formation, very high bottom-hole circulating temperatures is encountered (310-340 degF) which exceeds the operating limitation for the downhole drilling/formation evaluation tools. This resulted in multiple temperature-related failures, unplanned trips and long non-productive-time. It became necessary to provide solution to reduce the BHCT-related failures. Performed offset-wells-analysis to identify the BHT regime across the entire-field, create a heat-map and correlate/compare actual formation-temperatures with the formation-temperature-gradient provided by the operator (1.4-1.8 degF/100-ft). Drilling reports and MWD/LWD/wireline logs were reviewed/analyzed. Reviewed tools-spec-sheets, discovered most of the tools had a maximum-temperature-rating of 300-302 degF and were run outside-technical-limits. Observed temperature-related-failures were predominant in very long slim-laterals, which indicated that some of the heat was generated by high flow rate/RPM and solids in the system. Tried drilling with low-RPM/FR, did not achieve meaningful-temperature-reduction. After detailed risk-assessment and analysis on other contributing factors in the drilling process, opted to incorporate mud-chiller into the surface circulating-system to cool-down the mud going into the well. Upon implementation of the mud chiller system, observed up to 40 degF reduction in surface temperature (i.e. temperature-difference between the mud entering/leaving mud chiller). This was achieved because the unit was set-up to process at least twice the rate that was pumped downhole. Also observed reduction in the bottom-hole circulating temperature to below 300 degF, thus ensuring the drilling environment met the tool specifications. The temperature-related tools failure got eliminated. On some of the previous wells, wireline logging tools have been damaged due to high encountered downhole temperature as circulation was not possible prior-to or during logging operation. The implementation of the mud-chiller system has made it possible for innovative logging thru-bit logging application to be implemented. This allows circulation of cool mud across the entire open hole prior to deployment of tools to perform logging operation. This has made it possible for same logging tool to be used for multiple jobs without fear of tool electronic-components failure die to exposure to extreme temperatures. The long non-productive time due to temperature-related tool failures got eliminated. The numerous stuck pipes events due to hole deterioration resulting from multiple round trips also got eliminated. Overall drilling operations became more efficient. The paper will describe the drilling challenges, the systematic approach implemented to arrive at optimized solution. It will show how good understanding of drilling challenges and tailored-solutions delivers great gains. The authors will show how this system was used to provide a true step-change in performance in this challenging environment.

OnePetro

doi: 10.2118/214623-MS

SPE

SPE-214623-MS

SPE/IADC Middle East Drilling Technology Conference and Exhibition

Country:

Europe > United Kingdom (0.46)
North America > United States > Texas (0.28)
Asia > Middle East > UAE > Abu Dhabi > Abu Dhabi (0.15)

Industry: Energy > Oil & Gas > Upstream (1.00)

SPE Disciplines:

Well Drilling > Drilling Operations > Directional drilling (1.00)
Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)

Technology: Information Technology (0.68)

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Using Thermoelectric Generators (TEGs) for Electric Power Generation from Waste Heat in Geothermal Plants

Nourdanesh, Nader (University of Calgary, Department of Chemical and Petroleum Engineering, Calgary, CanadaEnergy Simulation Centre for Geothermal Systems Research) | Kantzas, Apostolos (University of Calgary, Department of Chemical and Petroleum Engineering, Calgary, CanadaEnergy Simulation Centre for Geothermal Systems Research)

OnePetroMarch, 2023

Abstract The application of Thermoelectric Generators for converting geothermal energy to electricity is investigated in this paper, considering the effects of various parameters on their efficiency. Using renewable energy is one of the latest solutions to tackle climate change, global warming, air pollution, the ozone layer hole, etc. In this regard, a thermoelectric generator (TEG), which is a device for converting heat energy to power, could be used in different renewable energy systems like solar or geothermal. Although their initial cost is lower than the other methods of converting thermal energy to electricity, their efficiency is lower than the most common techniques. Therefore, finding the optimum situation to increase the efficiency of combined devices with TEGs can increase the likelihood of using them in different industries. The parameters investigated in this paper were the temperature of the operating fluid in channels, the optimum mass flow rate, and the channel slope. The results have shown that with increasing temperature differences of the fluid in the channel, the efficiency of the designed system increased significantly. In addition, by increasing the mass flow rate of the operating fluid in the channel, power generation and the whole system efficiency increase up to a certain plateau value. Furthermore, the experimental results have proven that increasing the slope of the channel increased the amount of power generation but has not caused a noticeable change in their efficiency.

OnePetro

doi: 10.2118/212748-MS

SPE

SPE-212748-MS

SPE Canadian Energy Technology Conference and Exhibition

Country:

North America > United States (0.46)
North America > Canada (0.28)

Genre:

Research Report > New Finding (0.47)
Research Report > Experimental Study (0.47)

Industry:

Energy > Renewable > Geothermal (1.00)
Energy > Power Industry (1.00)
Energy > Oil & Gas > Upstream (1.00)

SPE Disciplines:

Reservoir Description and Dynamics > Non-Traditional Resources > Geothermal resources (1.00)
Production and Well Operations > Well & Reservoir Surveillance and Monitoring (1.00)
Health, Safety, Environment & Sustainability > Sustainability/Social Responsibility > Sustainable development (1.00)
Health, Safety, Environment & Sustainability > Environment (1.00)

Technology: Information Technology (1.00)

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Managing High Bottom-Hole Temperature Challenges in Slim Long Horizontal Wells: a Case Study from the Biggest Gas Field in the Middle East

Ovwigho, Efe Mulumba (Schlumberger) | Almomen, Mohammed Sami (Schlumberger) | Corona, Mauricio (Schlumberger) | Terrez, Jose (Schlumberger)

OnePetroMarch, 2023

Abstract The deep carbonate reservoir formation on this field has proven to be an extreme High-temperature (HT) environment for downhole equipment. While drilling the 5000 − 6500 ft 5-7/8" slim long laterals across this formation, very high bottom-hole circulating temperatures is encountered (310-340 degF) which exceeds the operating limitation for the downhole drilling/formation evaluation tools. This resulted in multiple temperature-related failures, unplanned trips and long non-productive-time. It became necessary to provide solution to reduce the BHCT-related failures. Performed offset-wells-analysis to identify the BHT regime across the field, create a heat-map and correlate/compare actual formation-temperatures with the formation-temperature-gradient provided by the operator (1.4-1.8 degF/100-ft). Drilling reports/MWD/LWD/wireline logs were reviewed/analyzed. Discovered the tools had a maximum-temperature-rating of 300-302 degF and were run outside-technical-limits. Temperature-related-failures were predominant in long slim-laterals, which indicated that some of the heat was generated by high flow rate/RPM and solids in the system. Tried drilling with low-RPM/FR, without meaningful-temperature-reduction. After detailed risk-assessment and analysis on other contributing factors in the drilling process, opted to incorporate mud-chiller into the surface circulating-system to cool-down the drilling mud. Upon implementation of the mud chiller system, observed up to 40 degF reduction in surface temperature (i.e. temperature-difference between the mud entering/leaving mud chiller). This was achieved because the unit was set-up to process at least twice the rate that was pumped downhole. Also observed reduction in the bottomhole circulating temperature to below 300 degF, thus ensuring the drilling environment met the tool specifications. The temperature-related tools failure got eliminated. On some of the previous wells, wireline logging tools have been damaged due to high encountered downhole temperature as circulation was not possible prior-to or during logging operation. The implementation of the mud-chiller system has made it possible for innovative logging through-the-bit logging application to be implemented. This allows circulation of cool mud across the entire open hole prior to deployment of tools to perform logging operation. This has made it possible for same logging tool to be used for multiple jobs without fear of tool electronic-components failure die to exposure to extreme temperatures. The long non-productive time due to temperature-related tool failures got eliminated. The numerous stuck pipes events due to hole deterioration resulting from multiple round trips also got eliminated. Overall drilling operations became more efficient. The paper will describe the drilling challenges, the systematic approach implemented to arrive at optimized solution. It will show how good understanding of drilling challenges and tailored-solutions delivers great gains. The authors will show how this system was used to provide a true step-change in performance in this challenging environment.

OnePetro

doi: 10.2118/214047-MS

SPE

SPE-214047-MS

Gas & Oil Technology Showcase and Conference

asia government, biggest gas field, case study, circulation, DEGF, Directional Drilling, drilling operation, europe government, exchanger, geothermal gradient, high bottom-hole temperature challenge, lateral, log analysis, Petroleum Engineer, presented, slim long horizontal well, uae government, united states government, Upstream Oil & Gas, well logging

Country:

Europe (1.00)
North America > United States > Texas (0.28)
Asia > Middle East > UAE > Abu Dhabi > Abu Dhabi (0.15)

Industry: Energy > Oil & Gas > Upstream (1.00)

Oilfield Places: Asia > Middle East > Israel > Southern District > Southern Levant Basin > Efe Field (0.97)

SPE Disciplines:

Well Drilling > Drilling Operations > Directional drilling (1.00)
Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)

Technology: Information Technology (0.49)

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Impact of Temperature Cross in Feed Bottom Exchanger

Albert, Eliot Robin Bruce (Kuwait Energy Basra Limited Subsidiary of United Energy Group Limited PAC - Block 9 Oil Field Basra - Iraq Eliot.Albert@kec.com.kw www.kuwaitenergy.co)

OnePetroMarch, 2023

Abstract The feed bottom exchanger is normally applied to improve the heat recovery, thereby reducing the external heat addition by means of live steam, re-boiler duty, or fired heater duty. A typical approach to heat integration to maximize the heat recovery using feed bottom exchangers would require overcoming the temperature cross in the exchangers. Thermodynamically, heat exchange beyond the cross temperature in a heat exchanger which is not truly countercurrent, is actually not possible. Hence penalty by means of excess area (extra shell) is required to overcome the cross temperature. Conventionally E-shells in series are applied to facilitate the heat exchange beyond the temperature cross. The F-shell exchanger, which is truly countercurrent, can also be used to achieve the same, but constrains such as physical and thermal leakage limit the usage. Recent advancement by the use of twisted tubes in F shell, avoids the physical leakage, because twisted tube bundle is a baffle free design. For the case under study, the heat exchange beyond the temperature cross is not likely to benefit. Hence the use of F shell exchanger will not be attractive. To overcome the temperature cross, the exchanger design is tuned by increasing number of passes or by increasing the number of exchangers in series, enabling more area requirement. An alternative proposal of heat exchange up to the temperature cross is delineated. The parameters that affect/impact the scenario are discussed. The feed bottom exchanger commonly used in units is hydro-treater reactor, amine regenerator and sour water stripper. In the present investigation Sour Water Stripper (SWS) is considered for the case studies.

OnePetro

doi: 10.2118/214169-MS

SPE

SPE-214169-MS

Gas & Oil Technology Showcase and Conference

Country: Asia > Middle East > Iraq (0.29)

Industry:

Materials (1.00)
Energy > Oil & Gas > Upstream (1.00)
Energy > Oil & Gas > Downstream (0.89)

SPE Disciplines:

Production and Well Operations (1.00)
Facilities Design, Construction and Operation > Processing Systems and Design (0.69)
Facilities Design, Construction and Operation > Natural Gas Conversion and Storage > Liquified natural gas (LNG) (0.68)
Health, Safety, Environment & Sustainability > Environment (0.47)

Add feedback

Managing High Bottom-Hole Circulating Temperature Challenges in Slim Long Horizontal Wells: A Case Study from a Giant Gas Field in the Middle East

Ovwigho, Efe Mulumba (Schlumberger) | Almomen, Mohammed Sami (Schlumberger) | Corona, Mauricio (Schlumberger) | Terrez, Jose (Schlumberger)

OnePetroFebruary, 2023

Abstract The deep carbonate reservoir formation on this field has proven to be an extreme High-temperature (HT) environment for downhole equipment. While drilling the 5000 - 6500 ft 5-7/8" slim long laterals across this formation, very high bottom-hole circulating temperatures is encountered (310-340 degF) which exceeds the operating limitation for the downhole drilling/formation evaluation tools. This resulted in multiple temperature-related failures, unplanned trips and long non-productive-time. It became necessary to provide solution to reduce the BHCT-related failures. Performed offset-wells-analysis to identify the BHT regime across the entire-field, create a heat-map and correlate/compare actual formation-temperatures with the formation-temperature-gradient provided by the operator (1.4-1.8 degF/100-ft). Drilling reports and MWD/LWD/wireline logs were reviewed/analyzed. Reviewed tools-spec-sheets, discovered most of the tools had a maximum-temperature-rating of 300-302 degF and were run outside-technical-limits. Observed temperature-related-failures were predominant in very long slim-laterals, which indicated that some of the heat was generated by high flow rate/RPM and solids in the system. Tried drilling with low-RPM/FR, did not achieve meaningful-temperature-reduction. After detailed risk-assessment and analysis on other contributing factors in the drilling process, opted to incorporate mud-chiller into the surface circulating-system to cool-down the mud going into the well. Upon implementation of the mud chiller system, observed up to 40 degF reduction in surface temperature (i.e. temperature-difference between the mud entering/leaving mud chiller). This was achieved because the unit was set-up to process at least twice the rate that was pumped downhole. Also observed reduction in the bottom-hole circulating temperature to below 300 degF, thus ensuring the drilling environment met the tool specifications. The temperature-related tools failure got eliminated. On some of the previous wells, wireline logging tools have been damaged due to high encountered downhole temperature as circulation was not possible prior-to or during logging operation. The implementation of the mud-chiller system has made it possible for innovative logging thru-bit logging application to be implemented. This allows circulation of cool mud across the entire open hole prior to deployment of tools to perform logging operation. This has made it possible for same logging tool to be used for multiple jobs without fear of tool electronic-components failure die to exposure to extreme temperatures. The long non-productive time due to temperature-related tool failures got eliminated. The numerous stuck pipes events due to hole deterioration resulting from multiple round trips also got eliminated. Overall drilling operations became more efficient. The paper will describe the drilling challenges, the systematic approach implemented to arrive at optimized solution. It will show how good understanding of drilling challenges and tailored-solutions delivers great gains. The authors will show how this system was used to provide a true step-change in performance in this challenging environment.

OnePetro

doi: 10.2118/213728-MS

SPE

SPE-213728-MS

Middle East Oil, Gas and Geosciences Show

Country:

Europe (1.00)
North America > United States > Texas (0.28)
Asia > Middle East > UAE > Abu Dhabi > Abu Dhabi (0.15)

Industry: Energy > Oil & Gas > Upstream (1.00)

Oilfield Places: Asia > Middle East > Israel > Southern District > Southern Levant Basin > Efe Field (0.97)

SPE Disciplines:

Well Drilling > Drilling Operations > Directional drilling (1.00)
Well Drilling > Drilling Fluids and Materials > Drilling fluid management & disposal (1.00)
Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)

Technology: Information Technology (0.49)

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Debottlenecking to Increase Gas Production with the Right Approach

Muthiah Ponnusamy, Saravanavel (SLB) | Moinuddin, Mohamed (SLB) | The, Lucio (SLB)

OnePetroFebruary, 2023

Abstract As a result of the present market conditions, there is an increased demand for gas. However, because of the limited production facilities available to meet the increasing demand, existing plants must be debottlenecked to handle greater gas capacities or new plants must be constructed. Constructing new plants requires longer lead times with significant capital expenditure (capex) investments. However, debottlenecking existing plants is a feasible option with a lower capex. Debottlenecking presents opportunities for quick deployments with marginal increases in production. This paper explains the methodology and approach used to debottleneck a gas processing plant to produce a 20% greater throughput than that provided by the original design. The methodology and approach included the deployment of a novel tray type in the gas sweetening unit (GSU) contactor and engineering checks throughout the facility for validation. A debottlenecking study was performed to increase the flow rate with minimal plant modifications within a minimum stoppage time. The challenges were to ensure the novel tray type would fit the designed hardware to improve the process, that all the studies were conducted in due time, and all plant modifications could be performed efficiently. This paper describes the success story and best practices regarding the plant capacity increase, the performance of a plant study to accommodate the debottlenecking, and the maintenance of safety standards.

OnePetro

doi: 10.2118/213735-MS

SPE

SPE-213735-MS

Middle East Oil, Gas and Geosciences Show

Country: Asia > Middle East (0.46)

Industry: Energy > Oil & Gas > Upstream (1.00)

SPE Disciplines:

Production and Well Operations > Well Operations and Optimization (1.00)
Production and Well Operations > Well & Reservoir Surveillance and Monitoring (1.00)
Facilities Design, Construction and Operation > Processing Systems and Design > Separation and treating (0.94)
Facilities Design, Construction and Operation > Processing Systems and Design > Gas processing (0.87)

Technology:

Information Technology > Artificial Intelligence > Natural Language > Explanation & Argumentation (0.54)
Information Technology > Artificial Intelligence > Machine Learning (0.54)

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Digital Twin Application for Boosting Oil Production, Predictive Analytics of Asset Integrity and Mid-Term Forecasting of Field Performance

Vorobev, Ilya (Gazrpomneft STC LLC) | Koshkin, Timur (Gazrpomneft NNGGF LLC) | Prokopev, Mikhail (Gazprom Neft Middle East B.V.) | Rakhmangulov, Yulay (Gazrpomneft STC LLC) | Kombarov, Semyon (Tyumen State University)

OnePetroOctober, 2022

Abstract There are often situations when readings of a large number of sensors installed at the field are used as needed, rather than on a systematic basis. The paper is devoted to the experience of building and using a Digital twin (DT) of the oilfield, history matched using instrument readings at the main nodal points from the well bottom to the tank farm. Digital twin is used to solve practical problems of selecting measures to increase production, specifying the maintenance program and chemical injections, overall allocating production by wells without direct measurements of production flow and forecasting in different time horizons the entire field production.

OnePetro

doi: 10.2118/211105-MS

SPE

SPE-211105-MS

ADIPEC

Country: Asia > Middle East > UAE (0.28)

Industry: Energy > Oil & Gas > Upstream (1.00)

Oilfield Places:

Asia > Kazakhstan > Mangystau Oblast > Precaspian Basin > Tengiz Field > Tengiz Formation (0.99)
Asia > Kazakhstan > Mangystau Oblast > Precaspian Basin > Tengiz Field > Korolev Formation (0.99)
Asia > Kazakhstan > Atyrau Oblast > Caspian Sea > Precaspian Basin > Kashagan Field (0.99)
(18 more...)

SPE Disciplines:

Reservoir Description and Dynamics > Fluid Characterization > Phase behavior and PVT measurements (1.00)
Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Downhole and wellsite flow metering (1.00)
Management > Asset and Portfolio Management > Integrated asset modeling (1.00)
(4 more...)

Technology:

Information Technology > Modeling & Simulation (1.00)
Information Technology > Data Science > Data Mining (0.76)
Information Technology > Communications > Networks (0.47)
Information Technology > Artificial Intelligence > Representation & Reasoning (0.46)

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Saudi Aramco Awards Winning Project

Abbate, Piero (TVP Solar SA) | Sparano, Silvio (TVP Solar SA)

OnePetroOctober, 2022

Abstract Operational since 26 December 2020 on Saudi Aramco's premises in Qurayyah (KSA), TVP Solar thermal plant has been conceived as a sizeable industrial pilot for Saudi Aramco to show the potential of energy and CO2 savings offered by the solar thermal technology of the Swiss company TVP Solar. Because of its proven performances, Qurayyah's TVP thermal solar plant has been awarded in 2021 with the Environment Excellence Award assigned to the See Water Injection Department (SWID) within Saudi Aramco and with the Energy Efficiency Award assigned both to SWID and the Research and Development Center (R&DC). Qurayyah's TVP Solar plant has been engineered to preheat from 93 °C up to 174 °C the water fed to a set of two diesel fueled boilers used to generate steam. Experience gained in Qurayyah shows that at this location 1 MW of peak thermal power requires 1,700 m of TVP Solar collectors (for about 3,000 m of total occupation space) to produce 1.5 GWhT/year, thus reducing fuel consumption by 200 m/year of diesel and avoiding 520 tons/year of CO2 emissions. The specific ability of TVP Solar collectors to harvest energy from diffuse light allowed the solar field to have its performance minimally impacted by fouling, even if the panels were never cleaned during more than one year of operations.

OnePetro

doi: 10.2118/210896-MS

SPE

SPE-210896-MS

ADIPEC

Country: Asia > Middle East > Saudi Arabia (1.00)

Genre: Personal > Honors (0.40)

Industry:

Government > Regional Government > Asia Government > Middle East Government > Saudi Arabia Government (1.00)
Energy > Renewable > Solar (1.00)
Energy > Oil & Gas (1.00)

SPE Disciplines:

Health, Safety, Environment & Sustainability > Sustainability/Social Responsibility > Sustainable development (1.00)
Health, Safety, Environment & Sustainability > Environment > Climate change (1.00)
Health, Safety, Environment & Sustainability > Environment > Air emissions (1.00)

Technology: Information Technology (1.00)

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An Overview of Retrofitting Abandoned Petroleum Wells for Geothermal Energy Production

Ashena, Rahman (Asia Pacific University of Technology & Innovation)

OnePetroOctober, 2022

Abstract Geothermal energy is considered a reliable, sustainable and abundant source of energy with minimized environmental impact. The extracted geothermal energy may be utilized for direct heating, or electricity generation. The main challenge to access this energy is tremendous capital expenditures required for drilling and completion. Therefore, this work discusses and evaluates retrofitting abandoned petroleum wells to geothermal as a commonly proposed solution to the mentioned challenge. There are many oil and gas wells globally which are not used for production, injection or other purposes. Well abandonment is commonly considered as an essential measure to ensure safety and integrity of these wells, bearing huge costs and concerns for the petroleum industry. By converting abandoned or nonactivated oil and gas wells to geothermal wells, it is claimed to be possible to produce geothermal energy and generate power. As a crucial stage for the claim verification and evaluation of feasibility or efficiency of this conversion, it is important to be aware of the practical and simulation studies which have been already implemented. Therefore, in this work, this work presents a comprehensive overview and analysis of 20 case studies published from different countries, followed by important downhole and surface parameters. In terms of downhole characteristics, production scenarios either open-loop or closed-loop, optimization of open-loop systems, borehole heat exchangers with their different types and dimensions, and insulations are covered. Next, surface cycles including organic Rankine cycle (ORCs), selection of circulation fluids, flow rates, and working fluids are covered, followed by produced and net powers with evaluation of coefficient of performance (COP) and thermal efficiency. This investigation shows there is good potential for using geothermal energy from abandoned and old petroleum wells.

OnePetro

doi: 10.2118/210861-MS

SPE

SPE-210861-MS

ADIPEC

Country:

Europe (1.00)
Asia > China (0.68)
Asia > Middle East > Iran (0.28)
(2 more...)

Genre: Research Report > New Finding (0.34)

Industry:

Government > Regional Government > North America Government > United States Government (1.00)
Energy > Renewable > Geothermal (1.00)
Energy > Oil & Gas > Upstream (1.00)

Oilfield Places:

North America > United States > Wyoming > Powder River Basin > NPR-3 > Teapot Dome Field > Wall Creek Formation (0.99)
North America > United States > Wyoming > Powder River Basin > NPR-3 > Teapot Dome Field > Tensleep Formation (0.99)
North America > United States > Wyoming > Powder River Basin > NPR-3 > Teapot Dome Field > Sussex Formation (0.99)
(10 more...)

SPE Disciplines: Reservoir Description and Dynamics > Non-Traditional Resources > Geothermal resources (1.00)

Technology: Information Technology > Modeling & Simulation (0.66)

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Enhancing Power Generation Utilizing Turbine Inlet Air Cooling (TIAC)

Kutbi, Jehad Fawzi (Saudi Aramco) | Georgiou, Ioannis (Saudi Aramco)

OnePetroOctober, 2022

Abstract Electricity demand is growing globally due to increasing population and growing economy, it is projected that the global energy demand will increase by 2.3% a year. One of the most reliable ways to generate electricity is by using gas turbines. Although gas turbines are efficient in terms of generating electricity, their power output significantly varies throughout the year due to temperature variance, especially in the summer time where the temperature can reach up to 50 C°. This is because gas turbines power output is proportional to the mass flow of air/fuel through the engine. Since the volumetric flow of air through the engine is essentially constant, mass flow therefore changes with temperature of the air entering the compressor of the gas turbine. When the ambient temperature is high, the power output and efficiency are reduced. Thus, by cooling the gas turbine inlet air, the turbine power output is significantly increased and its efficiency improves. Cooling the combustion air even by few degrees can improve the power output substantially. This is because cool air is denser and therefore gives the turbine a higher mass flow-rate and pressure ratio, resulting in increased turbine output and efficiency as much as 0.5% per degree Fahrenheit or about 1% per degree Celsius. Another advantages in cogeneration is the higher exhaust mass flows resulting in more steam generation. Turbine inlet cooling can be installed in most of the turbines of Saudi Aramco in order to increase their nominal capacity and improve their NOx emission. This paper will analyze the mechanism behind the turbine inlet cooling and will presents the results of a techno economical study conducted for retrofitting a TIAC system on the existing GE Frame VII gas turbines of Abu Safah and Qatif plant facilities.

OnePetro

doi: 10.2118/211308-MS

SPE

SPE-211308-MS

ADIPEC

air emission, asia government, carbon emission, chiller, climate change, compressors engines and turbines, Efficiency, exchanger, greenhouse ga emission, Implementation, Petroleum Engineer, reduction, Saudi Arabia government, Simulation, society, TIAC, turbine, Upstream Oil & Gas, utilizing turbine inlet air cooling

Country: Asia > Middle East > Saudi Arabia (0.71)

Industry:

Energy > Power Industry (1.00)
Energy > Oil & Gas > Upstream (1.00)
Government > Regional Government > Asia Government > Middle East Government > Saudi Arabia Government (0.56)

SPE Disciplines:

Health, Safety, Environment & Sustainability > Environment > Air emissions (0.71)
Health, Safety, Environment & Sustainability > Environment > Climate change (0.71)
Health, Safety, Environment & Sustainability > Sustainability/Social Responsibility > Sustainable development (0.67)
Facilities Design, Construction and Operation > Processing Systems and Design > Compressors, engines and turbines (0.55)

Technology: Information Technology (0.48)

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Managing High Bottom-Hole Temperature Challenges in Ultra-Slim Long Horizontal Wells

Using Thermoelectric Generators (TEGs) for Electric Power Generation from Waste Heat in Geothermal Plants

Managing High Bottom-Hole Temperature Challenges in Slim Long Horizontal Wells: a Case Study from the Biggest Gas Field in the Middle East

Impact of Temperature Cross in Feed Bottom Exchanger

Managing High Bottom-Hole Circulating Temperature Challenges in Slim Long Horizontal Wells: A Case Study from a Giant Gas Field in the Middle East

Debottlenecking to Increase Gas Production with the Right Approach

Digital Twin Application for Boosting Oil Production, Predictive Analytics of Asset Integrity and Mid-Term Forecasting of Field Performance

Saudi Aramco Awards Winning Project

An Overview of Retrofitting Abandoned Petroleum Wells for Geothermal Energy Production

Enhancing Power Generation Utilizing Turbine Inlet Air Cooling (TIAC)

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Collaborating Authors

exchanger