The scope of this document is to summarize the field trial of Expro FlowCaT and Geoservices GEM-Valve Wireless Electromagnetic Surface Controlled Sub-surface Safety Valve in Fiume Treste field, in sud of Italyt and provide a final technical evaluation. In 2007, COMP started a study about existing Surface Controlled Sub-surface Safety Valve, to have a complete knowledge of their status in worldwide wells and to make a statistic analysis of the most common failures.The control line‟s failure is the most critical, since it prevents the installation of a contingency WR-SCSSV, which would be impossible to control. In these cases, the only available contingency, till now, was the installation of a SSCSV (Sub-Surface Controlled Safety Valve), but it doesn‟t guarantee the same level of reliability as the SCSSV‟s: These valves are not controlled from the surface, they are not fail-safe and they are operated by particular events on the well (such as high flow rate or low pressure), which are very uncertain. To address this issue, COMP made a survey with valves‟ suppliers and a solution to, this problem was identified in the new wireless electromagnetic technology. After a strict “ISO-modified” qualification process and a 6-months field installation in a STOGIT gas storage well with monthly tests and a final slam test, both the considered Electromagnetic Wireless Surface Controlled Sub-surface Safety Valves: Expro 3.65” FlowCaT & Geoservices 3.72” GEM-VALVE are considered qualified and field proven to be installed in eni wells.

Many mature gas wells worldwide have had to be shut-in due to water loading in the production string, which occurs when the liquid's hydrostatic column pressure equals that of the reservoir pressure, stopping production. Periodically injecting surfactant chemicals from surface has been tried but is only a temporary solution. Continuos injection of a downhole foaming agent can be used to lift the water and restore gas production. If an injection line is not part of the completion string, an external injection line can be installed either with a rig workover or a rigless through-tubing installation. The first solution requires significant rig expense, and the second can cause loss of downhole safety-valve functionality. A more cost-effective, safer problem resolution method was needed.This paper describes the first ENI field trial of a Capillary Deliquification Safety System that can be retrofitted into existing wells with rigless intervention to quickly reinstate production. This method maintains safety valve functionality and eliminates an expensive well workover. The installation equipment includes a modified wireline-retrievable surface-controlled sub-surface safety valve (WR-SCSSV) with capillary tubing attached below. The injection method operates via the control system for the WR-SCSSV. The installation, which uses the existing control line of the safety valve to inject chemicals, does not require wellhead modification.The trial installation of the new system took place in a shut-in well in a Barbara offshore field in the Adriatic Sea. The trial showed that the system could provide a cost-effective alternative to well workovers and occasional surfactant treatments and will significantly increase hydrocarbon recovery from the reservoir while maintaining the well's safety level.

Objectives/Scope This paper summarizes the innovative peculiarities and the result of field trial installation on ENI well in South Italy of the new Insert Sucker Rod Surface Controlled Subsurface Safety Valve ISRSCSSV. The ISRSCSSV, combined to a modified lock mandrel, is sucker rod retrievable and is possible to install in a WRSCSSV landing nipple. It is a normally closed failsafe safety valve so the CL pressure keeps the valve open (Orsini 2018). Methods, Procedures, Process The innovation resides in a variable geometry sealing mechanism, able to shut in the annular area between the sucker rod and the valve external body. The sealing path is composed of a segmented tapered pads system located at the end of the elastic fingers, travelling along a cone housing. The ISRSCSSV combined with the Hybrid Pump determines a new approach for interventions on existing wells completed for spontaneous flowing without workover, representing a first fundamental step towards the application of the dual barrier policy in production wells. The Innovation allows safely operating wells and recovering oil otherwise not economically advantageous (Mennilli 2019). Results, Observations, Conclusions The ISRSCSSV applies when need to convert a spontaneous flowing o ESP wells to the sucker rod artificial lift. After the manufacturing of the ISRSCSSV, the related modified lock mandrel prototypes and the dedicated test fixture, the functional test performed as per API 14A (2015)/UNI EN ISO 10432 annex C (2004), was successful. Before the installation in ENI's well, a shallow test well equipped with all the necessary accessories to install and test the Hybrid Pump, and the downhole safety valve was completed, the test results were positive. On January 2020 ENI after attending the above tests, decided to run a field trial installation, function test, and retrieving in a well located in South Italy. On the field, after the ISRSCSSV installation, the safety valve lock mandrel was tested to verify the hold-down mechanism. The ISRSCSSV test was performed applying pressure inside the tubing against a wireline plug. Then closed the ISRSCSSV, bled off 50% of the wellhead pressure and performed a positive test as per API 14A (2015). The field test ended with the assembly retrieving applying the necessary over pull to release the lock mandrel retainer system. The overall result of the trial was considered positive. Novel/Additive Information ISRSCSSV represents the first safety valve existing in the body of literature for wells with sucker rod artificial lift system, allowing the compliance to the dual barrier policy. Moreover, this approach gives the possibility to install and retrieve the safety valve always with the rods string, with considerable time and subsequent cost saving, safeguarding the protection of the environment and the Oil Company image (Mennilli 2019).

The GasJack® type compression units installed on wellheads are a widely applied solution to mature gas wells with unloading problems. These are very reliable machines for manned well sites, requiring little maintenance, equipped with appropriate safety systems. However, for unmanned platforms and remote areas, it is mandatory to improve the GasJack® units with a telemetry control system. A dedicated R&D project has achieved such objective, through the following activities: "Feasibility Study", to evaluate the technical parameters and manned operations to include in the new system."Telemetry Technology Evaluation", to choose the most functional telemetry technology, by assessing the proper data communication system."GasJack® Unit Improvement", to identify the required modifications on the compressor unit, such as the replacement of existing components and the installation of a new control panel."Workshop Test and Certification", to certify the modified unit and verify its efficiency for the field test."Field Test", including an application in a remote and unmanned site, to restore production from a gas well. The results obtained during the project are quite remarkable. The installation in the remote well area was successfully performed. At stable conditions, the technology demonstrated to be fully remotely manageable; telemetry confirmed to be an excellent tool for communication. The gas well restored its production and, thanks to the continuous monitoring and management of settings, the machine allowed the optimization and stabilization of the gas rate and liquid flow (doubling the well production capacity). Therefore, the technology demonstrated that it can bring benefits in terms of wider application, well production increase, reduction of non-production time, simpler setting of parameters and unit operator costs minimization. This paper explains how to update/modify a standard wellhead compressor unit, in order to install a telemetric remote control system and replace existing components, thus allowing use in unmanned sites.

The well (Figure 1) of the case study presented in this paper is an oil producer from carbonate reservoir located in Southern Europe. Reservoir is characterized by a complex fracture network that increases the difficulties of production optimization actions, as for example water shut off interventions. This well is completed with a 4-1/2" liner extending to a 4-1/2" slotted liner inside a 6" open hole (OH). During the production time, the Water Cut (WC) has increased steadily finally reaching 94%, preventing the well from producing naturally. Log acquisition and interpretation, with Production Logging Tool (PLT) and Spectral Noise Logging (SNL), have shown that the water was coming from a fractures network laying behind the liner, to enter the top of the slotted liner despite swellable packers A and B. The lack of accessibility to this fractures network was therefore posing a challenge for an effective placement of a sealant gel.