[编者注：这个故事最初出现在 2020 年 1 月版的 E&P中。在这里订阅杂志 。] 

随着石油和天然气运营商努力优化成熟和边缘油田的生产，创新技术对于提高采收率和提高经济效益至关重要。

电潜泵 (ESP) 越来越多地被用作从井眼人工提升大量流体的有效且可靠的方法。传统的 ESP 系统需要作为油管或连续油管的一部分运行，电机位于钻孔组件的底部。这些泵可以根据油藏的单独生产和井眼特征进行配置，以控制和增强石油的举升。

最近，人们开发出了细长的电缆部署 ESP，可提供经济高效的可改造解决方案。通过消除对钻机的需求，运营成本大大降低，尤其是海上运营成本。然而，这些可改造的解决方案通常意味着井内现有的地下安全阀 (SSSV) 无法运行，因此需要替代解决方案。

Pragma Well Technology 正在开发一种先进的井下安全阀，为生产井改装的电缆部署 ESP 创建改进的井控工具。这种新型 ESP 安全阀使陆上和海上安装能够满足所有安全法规，同时简化部署和回收操作。

新挑战
在许多地区，符合 API 14A 要求的 SSSV 是生产井的法律要求。这些安全装置安装在上部井筒中，以在紧急情况下提供井液的遏制。这些阀门通常使用挡板式机构，并在完井期间并入生产油管中。

传统的钻机部署的 ESP 与生产油管一起在井内运行。它们的控制管线在环空中的管道外部延伸，因此可以在设备上方放置安全阀，以在管道内提供畅通无阻的密封。

然而，当将 ESP 改装到井上时，在不使用钻机且不更换生产油管的情况下，ESP 控制管线和输送电缆必须穿过油管内部。这会阻碍现有的挡板式 SSSV，因此需要额外的安全阀。

目前，操作员可以通过在现有阀门的轮廓中安装改进的阀门来解决此问题，并使用旧的 SSSV 控制线来驱动新阀门。然而，这些选项仅限于具有可绳索回收安全阀接头轮廓和相关控制管线的井，因此并非没有缺点。

新阀门必须精确地放入嵌件轮廓中，并且需要额外的表面设备进行安装。它通常需要几个耗时的过程来确保有效部署，并依赖于现有密封型材和阀门控制管线的完整性，这些管线可能已经在原位存在了10 多年。点蚀或腐蚀相当常见，这会降低密封的可靠性和整体安全性。

灵活且节省成本的设计
Pragma 先进的 ESP 安全阀专为改装 ESP 而设计，位于泵下方。它消除了对现有 SSSV、其密封件或控制线的任何依赖，提供了一款适合用途的安全工具。

该阀门可以采用不同的配置来部署，以适应现有的油井设置，为操作员提供了更大的灵活性。它可以作为下部 ESP 组件的集成部分运行，在生产油管的同一运行中进行部署和回收，从而减少安装时间。或者，它可以根据操作员的喜好单独安装在运行密封孔封隔器和钻孔 ESP 组件之间。

新技术
与其他安全阀不同，该装置不采用电动或液压控制线路，而是采用一种新颖的压差（流体升程）方法来打开和关闭它。当 ESP 运行并通过井眼提升流体时，就会产生这种压差。因此，阀门在 ESP 泵送时打开，在泵停止时关闭。

由于它不需要加压室、液压控制管线或电力，因此这种设计保证了可靠性。当 ESP 关闭时，它具有故障安全关闭机制，并且可以根据需要多次打开和关闭。该可回收技术还可应用于其他人工举升系统，包括毛细管柱、气举速度管柱、螺杆泵和喷射泵系统。

标准型号的额定温度为 120°C，针对更恶劣环境的额定温度为 170°C 的高温版本正在开发中。作为对操作员的额外保证，可以通过流入测试对阀门进行井内测试，以确认其在关闭时保持压力。此外，该阀门可以配置为允许在安装后从上方进行压力测试，但也有利于泵通能力。

ESP 安全阀采用新型增强材料和方法（包括增材制造）制成，有 3.5 英寸和 3.5 英寸两种尺寸可供选择。和 4.5 英寸。生产管材，提供紧凑、经济高效的解决方案。该设计和较小的井场占地面积为操作员提供了更大的安全性和可靠性保证，并降低了安装、操作和回收成本。ESP 安全阀技术是内部开发的，已经进行了多项测试，并将通过 API 14A 认证。

适应变化
随着石油和天然气行业不断寻求新技术来增强现有设备，供应链的不断适应至关重要。通过投资关键研发，有降低成本和优化生产的重大机会。

对 Tech Watch 有故事创意吗？此功能突出了领先的技术，有可能最终解决现实生活中的上游挑战。将您的故事想法提交给执行编辑詹妮弗·普雷斯利（jpresley@hartenergy.com）。

[Editor's note: This story originally appeared in the January 2020 edition of E&P. Subscribe to the magazine here.] 

As oil and gas operators strive to optimize production in mature and marginal fields, innovative technology is essential to enhance recovery and deliver improved economic benefits.

Electric submersible pumps (ESPs) are increasingly used as an efficient and reliable method for artificially lifting high volumes of fluids from wellbores. Traditional ESP systems need to run as part of the tubing or on coiled tubing, with the motor located at the bottom of the borehole assembly. The pumps can be configured to suit the individual production and wellbore characteristics of the reservoir to control and enhance the uplift of oil.

More recently, slimline cable-deployed ESPs have been developed that provide cost- and time-efficient retrofittable solutions. By eliminating the requirement for a rig, opex is drastically reduced, particularly offshore. However, these retrofittable solutions often mean the existing subsurface safety valve (SSSV) within the well is rendered inoperable, so an alternative solution is required.

Pragma Well Technology is developing an advanced downhole safety valve to create an improved well control tool for cable-deployed ESPs retrofitted to production wells. This new ESP safety valve enables onshore and offshore installations to meet all safety regulations while simplifying deployment and retrieval operations.

New challenges
In many regions, an API 14A qualified SSSV is a legal requirement for producing wells. These safety devices are installed in the upper wellbore to provide containment of well fluids in the event of an emergency. These valves generally use a flapper-style mechanism and are incorporated in the production tubing during completion.

Traditional rig-deployed ESPs are run in-hole along with the production tubing. Their control lines run outside the tubing in the annulus, so a safety valve can be placed above the device to provide an unimpeded seal within the tubing.

However, when an ESP is retrofitted to a well, without the use of a rig and without replacing the production tubing, the ESP control lines and conveyance cable must run through the inside of the tubing. This obstructs the existing flapper-style SSSV, therefore creating the requirement for an additional safety valve.

Currently, operators can resolve this by installing a modified valve into the profile of the existing one, with the old SSSV control line used to actuate the new valve. However, these options are limited to wells with wireline retrievable safety valve nipple profiles with associated control lines and as such are not without drawbacks.

The new valve must be dropped precisely into the insert profile and requires additional surface equipment for installation. It generally requires several time-consuming processes to ensure effective deployment and relies on the integrity of the existing seal profile and valve control lines, which may have been in situ for more than 10 years. Pitting or corrosion is fairly common, which can reduce the reliability of the seal and overall safety.

Flexible and cost-saving design
Pragma’s advanced ESP safety valve has been designed specifically for retrofitted ESPs and sits below the pump. It removes any reliance on the existing SSSV, its seals or control lines, delivering a fit-for-purpose safety tool.

Providing greater flexibility for operators, the valve can be deployed in varying configurations to suit the existing well setup. It can be run as an integrated part of the lower ESP assembly to be deployed and retrieved in the same run through the production tubing, thereby reducing installation time. Alternatively, it can be installed separately between running the seal bore packer and the borehole ESP assembly, depending on the operator’s preference.

Novel technology
Unlike other safety valves, instead of electric or hydraulic control lines, this device uses a novel method of differential pressure (fluid lift) to open and close it. This pressure differential is created when the ESP is operational and is lifting fluid through the wellbore. Therefore, the valve opens when the ESP is pumping and closes when it stops.

As it requires no pressurized chambers, hydraulic control lines or electrical power, this design safeguards reliability. It has a fail-safe closing mechanism when the ESP is switched off and can be opened and closed as many times as required. The retrievable technology also can be applied to other artificial lift systems including capillary strings, gas-lift velocity strings, progressive cavity pump and jet pump systems.

The standard model has a temperature rating of 120 C, and a high-temperature version rated to 170 C for harsher environments is being developed. As an added assurance to the operator, the valve can be tested in-hole via an inflow test to confirm that it holds pressure when shut. Additionally, the valve can be configured to allow a pressure test from above once installed but also facilitates pump-through capability.

Created using new and enhanced materials and methods, including additive manufacturing, the ESP safety valve is available in size variants for both 3.5-in. and 4.5-in. production tubing, providing a compact, cost-effective solution. The design and small wellsite footprint provide greater safety and reliability assurances to the operator as well as lowers installation, operation and retrieval costs. The ESP safety valve technology has been developed in-house with a number of tests already conducted and will be API 14A qualified.

Adapting to change
As the oil and gas industry continues to seek new technologies to enhance existing equipment, it is vital that the supply chain continues to adapt. By investing in critical R&D, there are significant opportunities to reduce costs and optimize production.

Have a story idea for Tech Watch? This feature highlights leading-edge technology that has the potential to eventually address real-life upstream challenges. Submit your story ideas to Executive Editor Jennifer Presley at jpresley@hartenergy.com.