geothermal gradient

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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Scalable Geothermal Energy Potential from Sedimentary Basins and Leveraging Oil and Gas Industry Experience: Case Studies from Texas Gulf Coast

Vivas, Cesar (University of Oklahoma) | Salehi, Saeed (University of Oklahoma) | Nygaard, Runar (University of Oklahoma) | Rehg, Danny (Criterion Energy Partners)

OnePetroMay, 2023

Abstract Geothermal energy has the potential to be a dependable source of power in the future. However, its development has mostly been limited to specific geographical areas or types of rocks. The western US has relatively high downhole temperatures compared to other regions, however, similar temperatures could be found in other regions by drilling deeper into sedimentary rocks. The oil and gas industry has developed highly efficient and cost-effective methods for drilling in sedimentary basins. The main challenge is adapting these wells for geothermal energy production. When comparing the cost per foot of drilling in typical sedimentary basins to drilling in granite or igneous rocks, there is a significant cost saving for the geothermal industry. Furthermore, techniques for hydraulic fracturing used in the oil and gas industry can also be applied to geothermal energy production. A prospective way to increase the production of geothermal energy is to utilize known reservoir rocks with storage and flow capacity that allows water or steam cycling in sedimentary basins. These rocks have the appropriate temperature, thickness, porosity, and permeability and are located at depths that do not make the drilling costs too high for the system to be economically viable. This study will explore the unique advantages that Texas's sedimentary basins can bring to the geothermal industry, including electricity generation and direct heat utilization. Some regions of the Texas Gulf Coast have medium-high geothermal gradients, providing the potential for geothermal energy development. Texas's numerous oil and gas wells can support geothermal direct-use projects, as demonstrated by case studies. An analysis of the levelized cost of energy using geothermal gradient data suggests that there are areas with the potential to produce geothermal power at a cost of 14 cents or less per kWh. Geothermal energy has the potential to significantly contribute to Texas's energy supply by providing a clean and renewable source of power to meet energy needs.

OnePetro

doi: 10.4043/32381-MS

OTC

OTC-32381-MS

Offshore Technology Conference

Drilling, gas industry experience, geothermal energy, geothermal gradient, north america government, Offshore Technology Conference, Reservoir Characterization, Salehi, scalable geothermal energy potential, sedimentary basin, structural geology, Texas, Texas Gulf Coast, united states government, Upstream Oil & Gas

Country: North America > United States > Texas (1.00)

Genre: Research Report (0.34)

Geologic Time: Phanerozoic > Cenozoic (0.93)

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 > Texas > Frio Formation (0.99)
North America > United States > Gulf of Mexico > Gulf Coast Basin (0.99)

SPE Disciplines:

Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
Reservoir Description and Dynamics > Non-Traditional Resources > Geothermal resources (1.00)

Technology: Information Technology (0.68)

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Geopressured Geothermal – Correlations to Offshore High Pressure High Temperature Geothermal Opportunities

Batir, Joseph F. (Petrolern LLC) | Gentry, Emilie N. (Petrolern LLC) | Soroush, Hamed (Petrolern LLC)

OnePetroMay, 2023

Abstract The northern Gulf of Mexico basin contains geopressured zones ideal for geothermal energy production, still to be explored. These systems are defined by primarily Eocene to Miocene sands that are confined by shale beds, which facilitates the formation of anomalously high pressures and temperatures. The overpressure in these zones results in an increased geothermal gradient, which makes geopressured zones of interest for geothermal exploration. Resources are commonly found at 3 to 6 km depth and reservoir fluid temperatures can range from 90 to 200°C. There has been a substantial amount of work done to understand these geopressured reservoirs on the Gulf Coast for geothermal potential. Many of these geopressured zones extend and exist offshore in the Gulf of Mexico. The knowledge and technical success of wells completed in these geopressured zones onshore can be transferred to understand how to produce a high pressure high temperature offshore well for geothermal power production. This paper will provide a review of previous work on geopressured geothermal zones in the Gulf Coast, the challenges with these systems, how these were overcome, and the knowledge transfer of those findings for offshore geothermal opportunities in high pressure high temperature wells.

OnePetro

doi: 10.4043/32407-MS

OTC

OTC-32407-MS

Offshore Technology Conference

correlation, geopressured reservoir, geopressured-geothermal program, Geothermal Exploration, geothermal gradient, Gulf Coast, knowledge management, offshore geothermal, Offshore Technology Conference, pleasant bayou, pressure high temperature geothermal opportunity, Reservoir Characterization, survey article, Texas, united states government, Upstream Oil & Gas

Country: North America > United States > Texas (1.00)

Genre: Overview (0.69)

Geologic Time: Phanerozoic > Cenozoic > Paleogene (0.35)

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

Oilfield Places:

North America > United States > Gulf of Mexico > Gulf Coast Basin (0.99)
North America > United States > Texas > Frio Formation (0.94)

SPE Disciplines:

Reservoir Description and Dynamics > Reservoir Characterization (1.00)
Reservoir Description and Dynamics > Non-Traditional Resources > Geothermal resources (1.00)

Technology: Information Technology > Knowledge Management (0.35)

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A Robust Screening Tool to Repurpose Hydrocarbon Wells to Geothermal Wells in Oklahoma

Ugarte, Esteban R. (The University of Oklahoma) | Salehi, Saeed (The University of Oklahoma)

OnePetroApril, 2023

Abstract Geothermal energy is a renewable energy that has vast potential due to its reliable energy supply. Its development has been related to specific geological locations with extremely high temperatures. However, depleted oil and gas reservoirs can produce geothermal energy from the subsurface. Repurposing this well can be a valuable tool to generate sustainable and steady energy for the state of Oklahoma due to its large number of wells used in the Oil and Gas industry. In fact, abandoned oil and gas wells are suitable candidates for conversion as these are environmental liabilities. The challenge is selecting which wells are good candidates for geothermal applications. This study aims to build an evaluation methodology to filter wells with a high potential for geothermal production. Three factors, temperature, proximity to the end user, and well integrity, are analyzed for evaluating possible candidates. Three datasets of temperature gradients were gathered from the Oklahoma Geological Survey, abandoned oil and gas wells from the Oklahoma Corporate Commission, and cities’ locations and populations from the US Census Bureau were combined. The objective is to evaluate the wells in Oklahoma to select promising candidates for repurposing for geothermal applications. Temperature prediction was made using Spatial Interpolation using Thiessen polygons, K-nearest Neighbors, and Kriging. K-nearest Neighbors exhibited the highest performance based on the evaluation metrics. Temperature prediction at an average true vertical depth of 6000 ft showed 26.7% or 4292 wells have more than 150 °F and can be converted for geothermal production. The shortest distance heuristic algorithm was used to calculate the shortest distance of each well to any city in Oklahoma. Before conversion, an evaluation of the well is required to assess the volumes and condition of the well; methods include statical analysis, logging, and evaluation techniques. These are discussed in this study. This study shows the high number of wells with the potential to be converted for geothermal applications converting a liability and environmental concern to a renewable energy-producing asset.

OnePetro

doi: 10.2118/213068-MS

SPE

SPE-213068-MS

SPE Oklahoma City Oil and Gas Symposium

Country: North America > United States > Oklahoma (1.00)

Genre:

Research Report > New Finding (1.00)
Research Report > Experimental Study (0.68)

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 > Oklahoma > Arkoma Basin > Cana Woodford Shale Formation (0.99)
North America > United States > Kansas > Cherokee Basin (0.99)
North America > United States > Arkansas > Arkoma Basin > Cana Woodford Shale Formation (0.99)
(6 more...)

SPE Disciplines:

Reservoir Description and Dynamics > Non-Traditional Resources > Geothermal resources (1.00)
Health, Safety, Environment & Sustainability (1.00)

Technology:

Information Technology > Artificial Intelligence > Representation & Reasoning (1.00)
Information Technology > Artificial Intelligence > Machine Learning > Statistical Learning > Nearest Neighbor Methods (1.00)

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Scalable Geothermal Energy Potential from Sedimentary Basins in Oklahoma

Vivas, Cesar (University of Oklahoma) | Salehi, Saeed (University of Oklahoma) | Nygaard, Runar (University of Oklahoma) | Rehg, Danny (Criterion Energy Partners)

OnePetroApril, 2023

Abstract Geothermal energy has vast potential as a reliable energy source of the future. However, its development has mostly been tied to specific geological locations or igneous rocks. Even though most western US regions have high thermal gradients compared to other places, higher temperatures are easily achievable by increasing the total depth in sedimentary rocks. The oil and gas industry has successfully mastered drilling sedimentary basins cost-effectively. Comparing cost/ft from typical sedimentary basins to granite or igneous rocks shows a tremendous difference. In addition, recent hydraulic fracturing technology transfer from the oil and gas industry can be deployed for geothermal applications. A potential new path toward expanded geothermal energy production is to use known porous and permeable reservoir rocks in appropriate sedimentary basins, where those formations have a sufficient temperature, thickness, porosity, and permeability, existing at depths that drilling time makes well construction costs economical for geothermal applications. In this paper, we will examine the unique potentials that sedimentary basins in Oklahoma offer to the geothermal industry for different end-user purposes, such as electricity generation or direct heat applications. The state has high geothermal gradients in some regions in the Arkoma Anadarko Basins that could be used for medium-temperature resources. Case studies from Oklahoma show how the many oil and gas wells in the state can enable geothermal direct-use projects. A state-wide levelized cost of energy analysis using geothermal gradient data indicates that there are areas with the potential to produce geothermal power at 14 cents/kWh or less. Geothermal energy has the potential to play a crucial role in Oklahoma's energy supply by offering a clean and renewable source of power that can fulfill energy demands.

OnePetro

doi: 10.2118/213094-MS

SPE

SPE-213094-MS

SPE Oklahoma City Oil and Gas Symposium

application, electricity, energy source, ga well, geothermal energy, geothermal gradient, Geothermal Resource, gradient, Modeling & Simulation, north america government, Oklahoma, power generation, Reservoir Characterization, scalable geothermal energy potential, sedimentary basin, united states government, Upstream Oil & Gas

Country: North America > United States > Oklahoma (1.00)

Geologic Time: Phanerozoic > Paleozoic (0.47)

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 > Gulf of Mexico > Gulf Coast Basin (0.99)
North America > United States > Texas > Meramec Formation > Meramec Formation > Mississippi Chat > Mississippi Lime > St. Louis Formation (0.94)
North America > United States > Texas > Meramec Formation > Meramec Formation > Mississippi Chat > Meramec Formation > St. Louis Formation (0.94)
(32 more...)

SPE Disciplines:

Reservoir Description and Dynamics > Reservoir Characterization (1.00)
Reservoir Description and Dynamics > Non-Traditional Resources > Geothermal resources (1.00)

Technology: Information Technology > Modeling & Simulation (0.46)

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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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Strategies for Prevention of Downhole Tool Failure Caused by High Bottomhole Temperature in Geothermal and HPHT Oil and Gas Wells

Khaled, Mohamed Shafik | Wang, Ningyu (The University of Texas at Austin) | Ashok, Pradeepkumar (The University of Texas at Austin) | Chen, Dongmei (The University of Texas at Austin) | van Oort, Eric (The University of Texas at Austin)

OnePetroMarch, 2023

Abstract High bottom hole temperature can lead to decreased downhole tool life in geothermal and high temperature / high pressure (HPHT) oil and gas wells. The temperature increase is exacerbated when circulation stops, e.g., during connection, tripping, well control situations, etc. While continuous circulation technology is an appropriate solution for managing temperature, it is not yet widely adopted in HPHT and geothermal drilling practices. This work investigates factors that impact downhole temperature and recommends strategies to better manage the temperature when continuous circulation is not available. An integrated thermo-hydraulic model was developed to capture the transient behavior of downhole temperature and was applied here to study the transient temperature profile when there is no fluid circulation. The model was validated using the open-source FORGE field dataset, with the mean absolute percentage error (MAPE) between 1-4%. In addition, hundreds of case scenarios were numerically studied to investigate the impact of several key factors on the downhole temperature. The evaluated factors include the pump-off time, type and physical properties of the drilling fluid, wellbore hydraulic diameter, reservoir temperature, geothermal gradient, total wellbore depth and profile, and operational parameters prior to stopping the circulation. The cooling effects of different drilling parameters were compared to a benchmark case of continuous circulation. A correlation map was generated to visualize the impact of those parameters on the downhole temperature distribution when circulation stops. A logarithmic relationship between the pump stop time and the downhole temperature was observed. For the FORGE case scenario, the downhole temperature increases by 27 °C and 48 °C after the pump stops for 30 and 60 minutes, respectively. It was observed that water-based mud with a high viscosity increases fluid convection heat resistance between the formation and wellbore. Also, drilling with a higher flow rate before stopping the pump can cool the near-wellbore formation faster and reduces the downhole temperature even after circulation ceases. Wells with high geothermal gradients, like FORGE wells, have higher temperature build-up during circulation stoppage than wells with low geothermal gradients targeting the same reservoir (formation) in-situ temperature. This study investigates the efficacy of different cooling strategies to avoid downhole temperature build-up when there is no circulation. It thereby facilitates the optimization of geothermal and HPHT well design and construction to prevent downhole tool failures. The developed correlation map can aid drilling engineers understand the impact of different drilling conditions on the downhole temperature.

OnePetro

doi: 10.2118/212550-MS

SPE

SPE-212550-MS

SPE/IADC International Drilling Conference and Exhibition

Country:

North America > United States > Texas (1.00)
Asia (1.00)
Europe (0.68)

Genre:

Overview (0.48)
Research Report (0.46)

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

Oilfield Places:

North America > United States > Texas > Permian Basin > Yeso Formation (0.99)
North America > United States > Texas > Permian Basin > Yates Formation (0.99)
North America > United States > Texas > Permian Basin > Wolfcamp Formation (0.99)
(25 more...)

SPE Disciplines:

Well Drilling > Drilling Operations > Directional drilling (1.00)
Well Drilling > Drilling Fluids and Materials > Drilling fluid selection and formulation (chemistry, properties) (1.00)
Well Drilling > Drilling Fluids and Materials > Drilling fluid management & disposal (1.00)
(3 more...)

Technology: Information Technology (1.00)

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Strategies for Prevention of Downhole Tool Failure Caused by High Bottomhole Temperature in Geothermal and High-Pressure/High-Temperature Oil and Gas Wells

Khaled, Mohamed Shafik (Bureau of Economic Geology, The University of Texas at Austin (Corresponding author)) | Wang, Ningyu (The University of Texas at Austin) | Ashok, Pradeepkumar (The University of Texas at Austin) | Chen, Dongmei (The University of Texas at Austin) | van Oort, Eric (The University of Texas at Austin)

OnePetroMarch, 2023

Summary High bottomhole temperature can lead to decreased downhole tool life in geothermal and high-pressure/high-temperature (HPHT) oil and gas wells. The temperature increase is exacerbated when circulation stops (e.g., during connection, tripping, and well control situations). While continuous circulation technology is an appropriate solution for managing temperature, it is not yet widely adopted in HPHT and geothermal drilling practices. This work investigates factors that impact downhole temperature (DHT) and recommends strategies to better manage the temperature when continuous circulation is not available. An integrated thermo-hydraulic model was developed to capture the transient behavior of DHT and was applied here to study the transient temperature profile when there is no fluid circulation. The model was validated using the open-source FORGE field data set, with the mean absolute percentage error between 1% and 4%. In addition, hundreds of case scenarios were numerically studied to investigate the impact of several key factors on the DHT. The evaluated factors include the pumps-off time, type and physical properties of the drilling fluid, wellbore hydraulic diameter, reservoir temperature, geothermal gradient, total wellbore depth and profile, and operational parameters before stopping the circulation. The cooling effects of different drilling parameters were compared to a benchmark case of continuous circulation. A correlation map was generated to visualize the impact of those parameters on the DHT distribution when circulation stops. A logarithmic relationship between the pump stop time and the DHT was observed. For the FORGE case scenario, the DHT increases by 27°C and 48°C after the pump stops for 30 minutes and 60 minutes, respectively. It was observed that water-based mud (WBM) with a high viscosity increases fluid convection heat resistance between the formation and wellbore. Also, drilling with a higher flow rate before stopping the pump can cool the near-wellbore formation faster and reduce the DHT even after circulation ceases. Wells with high geothermal gradients, like FORGE wells, have a higher temperature buildup during circulation stoppage than wells with low geothermal gradients targeting the same reservoir (formation) in-situ temperature. This study investigates the efficacy of different cooling strategies to avoid DHT buildup when there is no circulation. It thereby facilitates the optimization of geothermal and HPHT well design and construction to prevent downhole tool failures. The developed correlation map can aid drilling engineers in understanding the impact of different drilling conditions on the DHT.

OnePetro

doi: 10.2118/212550-PA

SPE

SPE-212550-PA

SPE Drilling & Completion

Country:

North America > United States > Texas (1.00)
Europe (1.00)
Asia (1.00)

Genre:

Overview (0.48)
Research Report (0.46)

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

Oilfield Places:

North America > United States > Texas > Permian Basin > Yeso Formation (0.99)
North America > United States > Texas > Permian Basin > Yates Formation (0.99)
North America > United States > Texas > Permian Basin > Wolfcamp Formation (0.99)
(25 more...)

SPE Disciplines:

Well Drilling > Drilling Operations (1.00)
Well Drilling > Drilling Fluids and Materials (1.00)
Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > HP/HT reservoirs (1.00)
(2 more...)

Technology: Information Technology (1.00)

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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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Drilling Heat Maps for Active Temperature Management in Geothermal Wells

Khaled, Mohamed Shafik (Bureau of Economic Geology, The University of Texas at Austin (Corresponding author)) | Chen, Dongmei (The University of Texas at Austin) | Ashok, Pradeepkumar (The University of Texas at Austin) | van Oort, Eric (The University of Texas at Austin)

OnePetroFebruary, 2023

Summary Geothermal energy has gained much attention as a promising contributor to the energy transition for its ability to provide a reliable, environmentally friendly source of heat and baseload power. However, drilling high-temperature (HT) reservoirs presents significant technical and economic challenges, including thermally induced damage to bits and downhole (DH) tools, increasing drilling time and cost. This paper introduces drilling heat maps for proactive temperature management in geothermal wells during well planning and real-time drilling operations phases to avoid thermally induced drilling problems. This study uses a transient hydraulic model integrated with a thermal model to predict the bottomhole circulating temperature (BHCT) while drilling geothermal wells. The model is used to generate a large volume (1,000s) of case scenarios to explore the impact of various cooling and other heat management strategies on the BHCT in the Utah FORGE field, used here as an example, covering a wide range of drilling parameters. Results are captured, visualized, and analyzed in convenient heat maps, illustrating the advantages of using such heat maps in geothermal well construction and real-time operations. Model validation with FORGE 16A(78)-32 well data and a west Texas case scenario shows good agreement between the modeling results and experimental data, with a mean absolute percentage error (MAPE) of less than 4%. There is a clear logarithmic relationship between the drilling flow rate and BHCT at a constant mud inlet temperature and a linear relationship between the mud inlet temperature and BHCT at a constant drilling flow rate. Pronounced variation of BHCT in geothermal wells is observed with mud type, mud weight, and mud viscosity. In addition, insulated drillpipe (IDP) technology is found to significantly reduce BHCT (14–44% on average for FORGE scenarios) compared to conventional drillpipe (CDP), particularly in wells with extended measured depth (MD) where other heat management technologies and strategies become less effective. Drilling heat maps can alert drilling engineers to strategies with the highest BHCT-lowering impact, allowing focused technology selection and decision-making regarding optimal temperature management during the geothermal well design phase. In addition, real-time heat maps are valuable for facilitating active temperature management and providing real-time guidance for optimal drilling parameters during daily drilling operations. In general, heat maps can help to avoid drilling problems related to the combination of HT and temperature limitations of DH equipment, which will benefit the safe and cost-efficient development of geothermal resources.

OnePetro

doi: 10.2118/210306-PA

SPE

SPE-210306-PA

SPE Journal

Country:

North America > United States > Texas (1.00)
Asia (1.00)

Genre: Research Report (0.46)

Industry:

Energy > Oil & Gas > Upstream (1.00)
Government > Regional Government > North America Government > United States Government (0.46)

Oilfield Places:

North America > United States > Texas > Permian Basin > Delaware Basin (0.99)
North America > United States > New Mexico > Permian Basin > Delaware Basin (0.99)
Asia > China > Sichuan > Sichuan Basin (0.99)

SPE Disciplines:

Well Drilling > Drilling Operations (1.00)
Well Drilling > Drilling Fluids and Materials (1.00)
Reservoir Description and Dynamics > Non-Traditional Resources > Geothermal resources (1.00)

Technology:

Information Technology > Visualization (1.00)
Information Technology > Architecture > Real Time Systems (1.00)

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