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The accumulation of liquid in deeper wells poses a critical problem as it significantly reduces the well's productivity index. One of the methods used to lift the accumulated liquid is the sucker rod pump system (SRP). However, lifting large volumes of liquid and associated gas to the surface artificially has been challenging, particularly with rod pump systems. To address this issue, a downhole gas separator can effectively be deployed below the pump intake to separate the free gas from the produced liquid. The gas separated downhole can then be extracted through the tubing-casing annulus while the liquid is artificially lifted through the tubing. The paper endeavors to provide a comprehensive review of recent advancements, technologies, and challenges related to downhole gas-liquid separators. The findings of this study can serve as a valuable guide for the development of downhole gas-liquid separation technologies in the industry, particularly for installation in unconventional wells. This review includes various laboratory evaluation tests and field examples that outline the efficiency and reliability of some downhole gas-liquid separators. There are two approaches implemented to design separators. The first approach is called static gas separation, based on the gravity principle. The second approach is dynamic gas separation, which is based on applying centrifugal forces through rotational speed. However, several downhole gas-liquid separators have low efficiency and lack an acceptable guideline for their optimum design. In some fields that suffer from liquid loading problems, it may be imperative to design and install an SRP and a downhole gas-liquid separator, to prevent gas lock problems. Based on the reviewed literatures, it was shown that centrifugal separators had better gas/liquid separation efficiency comparing to gravitational separators. Cyclone centrifugal separators consistently exhibit separation efficiencies ranging from 90% to 98%, whereas gravity-based separators typically achieve efficiency levels between 70% and 90%, depending on the design and operational variables. Centrifugal separators consistently deliver exceptional separation efficiencies, with effectiveness ranging from 90% to 99%. Moreover, the swirl tubes have showcased an approximate separation efficiency of 90% and effectively handle the fluctuating gas flow rates encountered in the well. This review comprehensively examines the advancements, limitations, and applications of downhole gas-liquid separators in oil and gas operations, specifically in conjunction with artificial lift systems. The paper aims to bridge the gap and differentiate between different types of downhole separators, offering researchers an extensive guide for their current and future investigations. Additionally, it proposes suitable technologies that can be deployed alongside the sucker rod pump (SRP) to enhance its efficiency in wells facing challenges related to liquid loading.
The accumulation of liquid in deeper wells poses a critical problem as it significantly reduces the well's productivity index. One of the methods used to lift the accumulated liquid is the sucker rod pump system (SRP). However, lifting large volumes of liquid and associated gas to the surface artificially has been challenging, particularly with rod pump systems. To address this issue, a downhole gas separator can effectively be deployed below the pump intake to separate the free gas from the produced liquid. The gas separated downhole can then be extracted through the tubing-casing annulus while the liquid is artificially lifted through the tubing. The paper endeavors to provide a comprehensive review of recent advancements, technologies, and challenges related to downhole gas-liquid separators. The findings of this study can serve as a valuable guide for the development of downhole gas-liquid separation technologies in the industry, particularly for installation in unconventional wells. This review includes various laboratory evaluation tests and field examples that outline the efficiency and reliability of some downhole gas-liquid separators. There are two approaches implemented to design separators. The first approach is called static gas separation, based on the gravity principle. The second approach is dynamic gas separation, which is based on applying centrifugal forces through rotational speed. However, several downhole gas-liquid separators have low efficiency and lack an acceptable guideline for their optimum design. In some fields that suffer from liquid loading problems, it may be imperative to design and install an SRP and a downhole gas-liquid separator, to prevent gas lock problems. Based on the reviewed literatures, it was shown that centrifugal separators had better gas/liquid separation efficiency comparing to gravitational separators. Cyclone centrifugal separators consistently exhibit separation efficiencies ranging from 90% to 98%, whereas gravity-based separators typically achieve efficiency levels between 70% and 90%, depending on the design and operational variables. Centrifugal separators consistently deliver exceptional separation efficiencies, with effectiveness ranging from 90% to 99%. Moreover, the swirl tubes have showcased an approximate separation efficiency of 90% and effectively handle the fluctuating gas flow rates encountered in the well. This review comprehensively examines the advancements, limitations, and applications of downhole gas-liquid separators in oil and gas operations, specifically in conjunction with artificial lift systems. The paper aims to bridge the gap and differentiate between different types of downhole separators, offering researchers an extensive guide for their current and future investigations. Additionally, it proposes suitable technologies that can be deployed alongside the sucker rod pump (SRP) to enhance its efficiency in wells facing challenges related to liquid loading.
A Technology Advancement of Multi-Laterals (TAML) level-4 completion was installed in the South China Sea in 2022. The unique design of this multilateral completion system increased efficiency and reliability in drilling and completing the well and enabled selective production from the main bore, the laterals, or both. It also incorporated a safe way of combining an openhole gravel pack job with a multilateral application. The main bore was completed with 9.625-in. casing. An 8.5-in. sidetrack was drilled and completed by the TAML level-4 junction and 7-in. liner was cemented in place. The key components of this multilateral completion system are an anchor packer system to temporarily isolate the main bore; a sidetrack whipstock and milling system to drill through 9.625-in. casing for 8.5-in. lateral bore; a robust 9.625 in. × 7 in. TAML level-4 junction system that combines a main bore production tieback assembly, main bore junction assembly, lateral bore junction assembly, and a junction drilling diverter isolation system. A 6-in. horizontal lateral bore was drilled through junction. An anti-swab openhole gravel pack system was installed in the 6-in. horizontal section to prevent sand production. For selective production from target zones in each lateral, a 3.5-in. intermediate string was installed. A specially designed multilateral well shrouded shearable tieback seal assembly was run back into the lateral bore. A standard sliding sleeve (SSD) and landing nipple were installed above the tieback assembly. Comingled production is achieved by leaving the SSD open, and selective production is achieved from the lateral bore by closing the SSD. Selective production from the main bore is achieved by leaving the SSD open and setting an intervention plug into the landing nipple. The upper production string was completed with an electrical submersible pump system. In early 2022, the full system was successfully installed for the first time in the region with zero health, safety, or environmental incidents and zero non-productive time. The lateral bore 7-in. liner and TAML level-4 multilateral junction were installed in a single trip, and the 7-in. liner cementing operation and excess cement cleanout were completed efficiently in that same trip. The 6-in. slim-hole drilling tool and openhole gravel pack sand control system both passed the multilateral junction with no hang up issues. The intermediate tieback string was successfully run back into lateral bore. The successful installation of entire well completion verified the high reliability and efficiency of this robust 9.625-in. ×7-in. multilateral well completion system. A traditional multilateral junction only hangs one 7-in. liner inside the 9.625-in. main bore casing. In contrast, this robust new TAML level-4 junction system enables designing the main bore junction assembly and the lateral bore junction assembly separately; the two assemblies can be installed in the same single trip together with cementing operation. The openhole gravel pack operation was then performed in a conventional way through the 7in cemented lateral liner. This drastically reduced the overall operational risk, by separating the operational risk of installing the multilateral junction and the open hole gravel pack job. This newly designed junction system and separate gravel pack operation were key enablers to complete this well smoothly and safely.
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