Selecting Artificial Lift or Deliquification Measures for Deep Gas Wells in The Sultanate of Oman

2019 ◽  
Author(s):  
Cornelis Veeken ◽  
Dawood Al Kharusi
Keyword(s):  
Sultanate Of Oman ◽  
Gas Wells ◽  
Artificial Lift

A New Artificial Lifting Technology for Gas Wells-Downhole Gas Compression

2013 ◽  
Vol 753-755 ◽  
pp. 2689-2692
Author(s):  
Xiang Liu ◽  
Zhi Chao Qiu ◽  
Chun Zhao
Keyword(s):  
Experimental Study ◽  
New Technology ◽  
Ordos Basin ◽  
Research Progress ◽  
Gas Wells ◽  
Liquid Loading ◽  
Artificial Lift ◽  
Gas Compression ◽  
Effective Drainage ◽  
Gas Fields

Downhole Gas Compression (DGC) is an entirely new powered artificial lift technology specifically for natural gas wells. The technology offers the opportunity to increase production by 30-50%, significantly improve reserves and delay the onset of liquid loading. Key application of DGC is for use in deeper partially depleted reservoir wells encountering liquid loading. The research progress of DGC is introduced in this paper and the results of theoretical and experimental study of DGC are investigated. Moreover, the adaptability and application prospect of this new technology is analyzed. There are many gas fields in China faced with problems about effective drainage and recovery enhancement, such as the mature gas fields in Sichuan and Ordos Basin. DGC will have a good application prospect in China and further study of the DGC technology is recommended.

Modeling the Effects of Various Liquid Droplet Sizes in Acoustic Deliquification Techniques

2021 ◽  
Author(s):  
Eiman Al Munif ◽  
Ahmed Alrashed ◽  
Kanat Karatayev ◽  
Jennifer Miskimins ◽  
Yilin Fan
Keyword(s):  
Fluid Dynamics ◽  
Natural Gas ◽  
Computational Time ◽  
Liquid Droplets ◽  
Gas Wells ◽  
Air Velocity ◽  
Liquid Loading ◽  
Artificial Lift ◽  
Tool Surface ◽  
Droplet Sizes

Abstract Liquid loading is a major challenge in natural gas wells. Enhancing the production in liquid loading natural gas wells using an acoustic liquid atomizer tool is proposed as a possible artificial lift method. The effect of different droplet sizes on the transport efficiency and the performance of the proposed technique during production are studied using Computational Fluid Dynamics (CFD) simulation. Also, the liquid behavior and fluid dynamics after applying the atomization mechanism are reviewed. In the model, the tool is placed axially in the middle of the gas/air flowing wellbore. To reduce computational time, the tool and pipe are cut symmetrically. The pipe diameter is 4 in, and the four injectors diameters are each 0.04 in. The orientation of the injectors is set to 90° with the sprayers facing sideways, while water liquid droplets are injected from the tool surface into the air flow at angles from 45° to the flow direction. Unstructured hybrid mesh is used to allow the cells to assemble freely within the complex geometry. Sensitivity tests were conducted with droplet sizes ranging between 30-300 µm. The CFD results showed that water liquid droplets of size 30 µm followed the pathway along the tool surface due to the low mass of the droplets and high air velocity. This phenomenon is called wall impingement and occurs where the droplets are very small and clustering on the wall. The 200 and 300 µm water liquid droplets kept their inertial high chaotic movements in all directions within the computational fluid domain due to the increased weight of the droplets. These larger sized droplets withstand the backpressure from high turbulent air velocity and tend to keep their inertial turbulent movement. This research presents a set of CFD results to further evaluate acoustic atomization as a possible artificial lift technique. This technique has never been commercially applied in the oil and gas industry, and continued evaluation of such methods is a vital addition to the industry as it brings the potential for new lower cost artificial lift technologies. If completely developed, this technique can bring a cost-effective solution compared to conventional artificial lift methods.

Sustaining Oil and Gas Fields by Using Multiphase Gas Compression to Increase Production and Reserves, and Lower Operating Costs and Environmental Emissions Footprint

2021 ◽  
Author(s):  
Robert A Perry ◽  
Jeremy M Pitts ◽  
Andrei M Strikovski ◽  
Utkarsh Sinha
Keyword(s):  
Co2 Emissions ◽  
Field Data ◽  
Oil And Gas ◽  
Operating Cost ◽  
Late Life ◽  
Operating Costs ◽  
Gas Wells ◽  
Artificial Lift ◽  
External Power Source ◽  
Environmental Emissions

Abstract A multiphase compressor has been developed that provides: compression ratios up to 40:1, the ability to handle multiphase and slugging flow, and a very broad and flexible operating range allowing it to be positioned near the wellhead. Currently the product is targeted at onshore unconventional fields, and field data have been collected on such fields. For deployment to onshore unconventional fields the multiphase compressor has been packaged within a system so that it is easily transportable and fully self-contained, requiring no external power source or utilities. Also, minimal effort is required to tie in at the wellpad (just process connections in and out), no downhole intervention is needed, and typically no site preparations are required, which allow it to be easily relocatable with minimal sunk investment cost. Onshore applications include: Artificial lift from surface to increase production and reserves, and reduce operating costs – applicable to both oil wells with moderate quantities of gas present, and gas wells suffering from liquid loading. Field data show production enhancement of up to 300% versus alternative forms of artificial lift. ‘Frac hit’ recovery to restore parent well production more quickly (by accelerated recovery of preload or ‘frac hit’ fluids from parent wells) – applicable to both oil and gas wells. Field data show accelerated fluid removal versus alternative forms of artificial lift and reservoir studies indicate around an order of magnitude faster recovery of fluids. Lower methane and CO2 emissions and operating costs from field operations – operator intensive flowbacks to open top tanks to kick wells off can instead be achieved with the multiphase compressor, which also avoids the methane emissions to the environment associated with open top tank flowbacks or CO2 emissions from flaring. Lower methane and CO2 emission field development options – by enabling multiphase gathering to centralized facilities, the emissions associated with poor pad separation and the associated fugitive emissions from on-site storage and movement of volatile liquids can be eliminated, and at the same time eliminating operating costs associated with intensive distributed operations such as road tanker export of oil from wellpads. Additionally, abandonment of late life conventional oil and gas reservoirs and wells can be deferred by avoiding slugging well flows for longer – adding both production and reserves, and removing the operating cost associated with kicking off wells. For land conventional well applications the same multiphase compressor and package can be deployed as for unconventional fields – and the system packaging can be easily adjusted to deploy to offshore platforms. The multiphase compressor has also been redesigned for subsea, and uses the same principles of operation to provide unique benefits for subsea applications: particularly for late life gas wells to add more production and reserves than would be possible from existing subsea multiphase boosting. Operators will be able to deliver more production and reserves from their existing assets, reduce operating costs, and lower environmental emissions from their production operations.

The Use of Umbilicals as a New Technology of Artificial-Lift Operation of Oil and Gas Wells without Well Killing when Workover

2012 ◽  
Author(s):  
Alexander Nikolaevich Drozdov ◽  
Evgeny Alexandr Malyavko ◽  
Yaroslav L. Alekseev ◽  
Andrey Viktorovich Robin ◽  
Aleksey Ivanovich Alekseev ◽  
...  
Keyword(s):  
Oil And Gas ◽  
New Technology ◽  
Gas Wells ◽  
Artificial Lift ◽  
Oil And Gas Wells
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