Overview of Opportunities and Challenges of Electrical Submersible Pumps ESP in the Geothermal Energy Production Systems

2021 ◽  
Author(s):  
Pejman Shoeibi Omrani ◽  
Kaj Van der Valk ◽  
Wim Bos ◽  
Eduard Nizamutdinov ◽  
Laurens Van der Sluijs ◽  
...  
Keyword(s):  
Geothermal Energy ◽  
Energy Production ◽  
Production Systems ◽  
Submersible Pump ◽  
Geothermal Systems ◽  
Geothermal Brine ◽  
Electrical Submersible Pumps ◽  
Geothermal Wells ◽  
Electrical Submersible Pump ◽  
System Designs

Abstract The electrical submersible pump (ESP) is an essential and critical component in most low-enthalpy geothermal wells where high volumes of hot (up to 120°C) and harsh geothermal brine is required to be transported to the surface. Despite a great deal of knowledge and experience in the design and operation of ESP in the petroleum and water sector, reliability of geothermal ESPs requires further improvement. Frequent failures have been observed that resulted from sub-optimum design, installation and operation of these systems which made the lifetime of them shorter than the expected 5-7 years. In this paper we summarize the typical conditions in low-enthalpy geothermal systems (specifically in the Netherlands) and several observed reliability challenges. Lastly, we will discuss the gaps between the petroleum, water and geothermal practices and identify a list of R&D opportunities to better understand the geothermal ESP failures and improve ESP reliability. Testing ESPs in realistic geothermal conditions and a proper monitoring of the well-ESP system is crucial to improve the reliability of existing ESP designs and can enable the development of new geothermal ESP system designs.

scholarly journals An analysis of thermodynamic properties in both traditional and enhanced geothermal systems to compare thermal efficiencies

2017 ◽  
Vol 4 ◽  
pp. 103-120
Author(s):  
Samuel Peter Martin ◽  
Alexander Richmond Perry ◽  
Kirill Lushnikov
Keyword(s):  
Energy Source ◽  
Renewable Energy Source ◽  
Geothermal Energy ◽  
Energy Production ◽  
Enhanced Geothermal Systems ◽  
System Efficiency ◽  
Geothermal Systems ◽  
Average Efficiency ◽  
Naturally Occurring ◽  
Geothermal Environments

This meta-study draws upon previous research on both Enhanced Geothermal Systems (EGS) and traditional geothermal systems (GS), using these findings to compare and investigate the thermal efficiency of each system. Efficiency calculations include reservoir enthalpy, maximum drilling well temperature, power output (per unit mass of liquid) and mass flow rate of these systems to determine whether EGS’s are viable as an alternative, more readily available renewable energy source. This meta-study suggests that EGS are more viable than naturally occurring GS in the context of future geothermal energy production as they perform with a similar average efficiency of 10-15% and, in addition, can be used in a wider range of geothermal environments.

Repurposing Oil & Gas Wells and Drilling Operations for Geothermal Energy Production

2021 ◽  
Author(s):  
Robert M. Pilko ◽  
Nicole Rita Hart-Wagoner ◽  
Andrew J. Van Horn ◽  
Joseph A. Scherer
Keyword(s):  
Geothermal Energy ◽  
Energy Production ◽  
Oil And Gas ◽  
Production Systems ◽  
Capital Allocation ◽  
Low Carbon ◽  
Low Carbon Economy ◽  
Oil And Gas Fields ◽  
Well Design ◽  
High Level

Abstract This paper explores a market solution for Operators’ companies to compound their investments in wells, fields, and infrastructure in a low carbon world by applying improved well design, drilling and completion technologies that are adapted to a new generation of geothermal energy production systems. The paper frames challenges posed to the upstream industry by the movement to a low carbon economy, including the climate transition risks related to societal, regulatory, and capital allocation trends. It then examines the technical challenges and solutions related to repurposing oil and gas fields and wells for geothermal energy production and makes high-level recommendations for Operators interested in accessing this new market for geothermal energy - as well as satisfying Environmental, Social and Corporate Governance (ESG) investors.

Test and application of electrical submersible pump units at White Tiger field

2019 ◽  
Vol 10 ◽  
pp. 82-86
Author(s):  
A.N. Ivanov ◽  
◽  
V.A. Bondarenko ◽  
M.M. Veliev ◽  
E.V. Kudin ◽  
...  
Keyword(s):  
Submersible Pump ◽  
Electrical Submersible Pump ◽  
White Tiger

Smoothing and expansion of the experimental mode shapes of an electrical submersible pump

2021 ◽  
Vol 229 ◽  
pp. 108975
Author(s):  
R.H.R. Gutiérrez ◽  
U.A. Monteiro ◽  
C.O. Mendonça
Keyword(s):  
Mode Shapes ◽  
Submersible Pump ◽  
Electrical Submersible Pump

Data Echoes: Sound, Evidence, and Acoustic Methods in Energy Landscapes

2021 ◽  
pp. 016224392110345
Author(s):  
James Maguire
Keyword(s):  
Geothermal Energy ◽  
Energy Production ◽  
Model Building ◽  
Acoustic Method ◽  
Time Frame ◽  
Energy Landscapes ◽  
Geological Evidence ◽  
Temporal Form ◽  
Acoustic Methods ◽  
Intractable Problem

This paper explores an informal acoustic method developed by a group of industrial geologists working in geothermal energy landscapes in the southwest of Iceland. Through a series of ethnographic descriptions, this paper renders the work these geologists carry out in sonic terms, emphasizing how they use their bodies as sonic detectors in the production of geological evidence. Sound, the paper argues, is what allows geologists to make the intractable problem of volcanic cooling doable. It does this by differentiating two forms of evidence. Primary evidence, which ends up as data in geological reports, and secondary sonic evidence, which is what establishes that this primary evidence is, in fact, evidence. The paper introduces the concept data echoes as a way to think about how sound articulates between these evidential protocols. As echo, sound works as an outside, which, while remaining external to official protocols of knowledge production, nevertheless helps to constitute distinctions that are meaningful to the production of those categories. As data echoes through the various moments of data capture, analysis, and model building, sound’s temporal form helps to predict the time frame of volcanic cooling, as it affects both the immediate energy production scenarios and the long durée of volcanic time.

Pushing 30 Years Multiple Brown Fields Limits Through Artificial Lift and Facilities Improvement

2021 ◽  
Author(s):  
Mohd Hafizi Ariffin ◽  
Muhammad Idraki M Khalil ◽  
Abdullah M Razali ◽  
M Iman Mostaffa
Keyword(s):  
New Technology ◽  
Lessons Learned ◽  
Oil Fields ◽  
Submersible Pump ◽  
Large Space ◽  
Gas Well ◽  
Wellhead Pressure ◽  
Artificial Lift ◽  
Electrical Submersible Pump ◽  
Gas Lift

Abstract Most of the oil fields in Sarawak has already producing more than 30 years. When the fields are this old, the team is most certainly facing a lot of problems with aging equipment and facilities. Furthermore, the initial stage of platform installation was not designed to accommodate a large space for an artificial lift system. Most of these fields were designed with gas lift compressors, but because of the space limitation, the platforms can only accommodate a limited gas lift compressor capacity due to space constraints. Furthermore, in recent years, some of the fields just started with their secondary recovery i.e. water, gas injection where the fluid gradient became heavier due to GOR drop or water cut increases. With these limitations and issues, the team needs to be creative in order to prolong the fields’ life with various artificial lift. In order to push the limits, the team begins to improve gas lift distribution among gas lifted wells in the field. This is the cheapest option. Network model recommends the best distribution for each gas lifted wells. Gas lifted wells performance highly dependent on fluid weight, compressor pressure, and reservoir pressure. The change of these parameters will impact the production of these wells. Rigorous and prudent data acquisitions are important to predict performance. Some fields are equipped with pressure downhole gauges, wellhead pressure transmitters, and compressor pressure transmitters. The data collected is continuous and good enough to be used for analysis. Instead of depending on compressor capacity, a high-pressure gas well is a good option for gas lift supply. The issues are to find gas well with enough pressure and sustainability. Usually, this was done by sacrificing several barrels of oil to extract the gas. Electrical Submersible Pump (ESP) is a more expensive option compared to a gas lift method. The reason is most of these fields are not designed to accommodate ESP electricity and space requirements. Some equipment needs to be improved before ESP installation. Because of this, the team were considering new technology such as Thru Tubing Electrical Submersible Pump (TTESP) for a cheaper option. With the study and implementation as per above, the fields able to prolong its production until the end of Production Sharing Contract (PSC). This proactive approach has maintained the fields’ production with The paper seeks to present on the challenges, root cause analysis and the lessons learned from the subsequent improvement activities. The lessons learned will be applicable to oil fields with similar situations to further improve the fields’ production.

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