Well stimulation optimization and verification

Abstract

A system for providing safe well access for hydraulic, mechanical, and optical intervention operations to increase performance of a reservoir formation, comprising a deployment package that is a marinized assembly, comprising a connection housing for connecting the deployment package to a subsea tree, wherein the connection housing has one or more bores to access a well; one or more well intervention modules attached to the connection housing that are configured to access the well; fluid connection path to the well having one or more barrier valves; a first access opening to the well with one or more barrier valves; and a second access opening to the well for deploying an optical fiber system, wherein the optical fiber system comprises: (i) a deployable device; (ii) one or more downhole sensing fibers; (hi) a connection to provide communication to an optical jumper; and (iv) a retaining device..

Description

Well Stimulation Optimization and Verification Docket No. P-2149-38368-0007 Customer No.174715 IN T H E U N I T E D S T A T E S R E C E I V I N G O F F I C EO F T H E P A T E N T C O O P E R A T I O N T R E A T YWell Stimulation Optimization and Verification INVENTORS Christopher Mancini - Houston, TX (US) Hans Kros – Cypress, TX (US) Carter Kacal – Houston, TX (US) David Macfarlane – The Woodlands, TX (US) APPLICANT Caltex Oil Tools, LLC, Tomball, TX (US) CROSS-REFERENCE TO RELATED APPLICATIONS

[0001] This application claims the benefit of priority under 35 U.S.C. §119(e) to provisionalpatent application U.S.63 / 699,258, filed on September 26, 2024. BACKGROUND OF THE INVENTION

[0002] 1. Field of the Invention

[0003] The present invention relates in part to devices and methods used in subsea oil and gaswell intervention or stimulation operations, and more particularly to such devices and methods which include fiber optic sensors to monitor well conditions and reservoir performance.

[0004] 2. Background and Prior Art

[0005] The focus for increased oil and gas production has historically been exploration, butwith maturing assets and increasing focus towards renewable energy sources, optimization of existing assets to assure, maintain or increase production levels will become the focus and not new discoveries. Accelerating production and increasing total recovery of existing fields is more cost- effective than new-field equivalents, also lowering CO2 per barrel. -1 -PD.53614291.1Well Stimulation Optimization and Verification Docket No. P-2149-38368-0007 Customer No.174715

[0006] While new wells will continue to be installed and new fiber optic installations installedwithin these wells will provide improved sensing capabilities for future production optimization, this invention focuses on systems and methods to provide improved sensing capabilities into existing wells, providing improved optimization capability.

[0007] Typically, there are four main reasons to plan a well intervention campaign: (1) wellintegrity issues, (2) production enhancement and optimization, (3) safeguarding, and (4) abandonment. Deploying a fiber optic sensing device into a well as part of a planned intervention campaign will provide an increased understanding of the condition of the well and the performance of the reservoir. The invention defined within this document provides increased sensing capabilities in each of these instances.

[0008] Well Stimulation and Acid Injection

[0009] Well stimulation of subsea wells by means of acid injection or other chemicals injectedinto the producing formation improves the production performance of the reservoir by restoring or improving its permeability. Various parameters such as the acid type and chemical mix and strength, the rate, volume and pressure at which the fluid is pumped, and the soak time are largely based on experience from past operations and a knowledge of the specific geology of the formation being stimulated. Optimized production and recovery rates may be further improved by introducing higher levels of data measurement of the flowing well before and after stimulation to improve the understanding of the reservoir and its characteristics more significantly.

[0010] The treatment of a reservoir formation involves use of a stimulation fluid containing areactive acid. In sandstone formations, the acid reacts with the soluble substances in the formation matrix to enlarge the pore spaces. In carbonate formations, the acid dissolves the entire formation matrix. In each case, the matrix acidizing treatment improves the formation permeability to enable enhanced production of reservoir fluids. Matrix acidizing operations are ideally performed at a high rate, but at treatment pressures below the fracture pressure of the formation. This enables the acid to penetrate the formation and extend the depth of treatment while avoiding damage to the reservoir formation. Acidizing may be commonly performed on new wells to maximize their initial productivity and on aging wells to restore productivity and maximize the recovery of the energy resources. Since geologic formations are never homogeneous, blends (particularly for sandstone -2 -PD.53614291.1Well Stimulation Optimization and Verification Docket No. P-2149-38368-0007 Customer No.174715 formations) of hydrochloric acid (HCl) and hydrofluoric acid (HF) may usually be pumped with the blend ratios based on the formation mineralogy.

[0011] Once the acid job has been pumped and allowed to soak, the well is brought onproduction. When this is done, the spent acid is produced along with the oil, gas, and water in theformation. Since the acid is chemically consumed when it contacts the formation, the recovered fluid is relatively benign.

[0012] Fiber Optic Sensing Systems

[0013] Several fiber optic sensing systems and techniques may be employed in subterraneanoperations to characterize and monitor wellbore and / or formation properties, such as, but not limited to Distributed Temperature Sensing (DTS), Distributed Acoustic Sensing (DAS) and Distributed Strain Sensing (DSS). These sensors may be used, but not limited to, production or injection profiling, well stimulation, flow assurance, well integrity or reservoir integrity monitoring, among others. Fiber optic monitoring is a cost-effective means of acquiring real-time, high- resolution and accurate data at discrete locations along the wellbore. System reliability is improving, and it reduces the reliance on downhole gauges and associated electronics being located downhole, with subsea optical fibers and wet-mate connectors providing a communication path from the downhole sensing fiber to the surface located interrogator unit to interpret the data. For downhole sensing fiber currently being installed in subsea wells, the fiber optic lines and connections are typically part of the subsea tree and tubing hanger assemblies and mated during their subsea installation, with the sensing fiber located in the well annulus between the completion tubing and the production casing, and provide real-time pressure, temperature, flow and even leak detection information amongst other things, during the life of the well. Within this invention, the fiber sensing system is deployed during well intervention activities to effectively upgrade a mature well, installed many years ago and prior to current technology availability. This effectively upgrades the mature well to have the same measurement capabilities and latest technology as wells being installed today. Furthermore, this equipment is installed under safe well control conditions, enabling verification of successful remediation work by measuring well and / or reservoir conditions before and after the intervention work has been performed. -3 -PD.53614291.1Well Stimulation Optimization and Verification Docket No. P-2149-38368-0007 Customer No.174715 BRIEF DESCRIPTION OF THE DRAWINGS

[0014] For a further understanding of the nature, objects, and advantages of the presentinvention, reference should be had to the following detailed description, read in conjunction with the following drawings, wherein like reference numerals denote like elements.

[0015] Figure 1 illustrates the full system of equipment and connections associated with wellintervention for hydraulic stimulation with fiber optic sensing capability.

[0016] Figure 2 illustrates a schematic example of an optical fiber sensing deployment devicemounted on top of a hydraulic stimulation device.

[0017] Figure 2a illustrates an embodiment where an optical fiber sensing deployment unit islocated in parallel with the hydraulic stimulation device to access a concentric bore subsea tree.

[0018] Figure 2b illustrates an embodiment where a mechanical intervention device is locatedin parallel with the hydraulic stimulation device to access a concentric bore subsea tree.

[0019] Figure 2c illustrates an embodiment where an optical fiber sensing deployment deviceworks in parallel with a mechanical intervention device to access a concentric bore subsea tree.

[0020] Figure 2d illustrates an embodiment where an optical fiber sensing deployment deviceworks in parallel with the stimulation unit to access a dual bore subsea tree using a bore selection device within the connector housing.

[0021] Figure 2e illustrates an embodiment where a mechanical intervention device works inparallel with the hydraulic stimulation device to access a dual bore subsea tree using a bore selection device within the connector housing.

[0022] Figure 2f illustrates an embodiment where an optical fiber sensing deployment deviceworks in parallel with a mechanical intervention device to access a dual bore subsea tree using a bore selection device within the connector housing.

[0023] Figures 3a and 3b illustrate an example of an optical fiber sensing deployment deviceintegrated into the WST.

[0024] Figure 4 illustrates a cross-section view of the WST showing the hydraulic barrier valvesin parallel with the optical deployment device. -4 -PD.53614291.1Well Stimulation Optimization and Verification Docket No. P-2149-38368-0007 Customer No.174715

[0025] Figure 5 illustrates an alternative view of a cross-section view of the WST showing thehydraulic barrier valves in parallel with the optical deployment device

[0026] Figure 6 illustrates a close-up external view of the optical fiber deployment deviceshowing one possible configuration with the retaining mechanism operated via an ROV panel on the WST structure, and the optical connection exiting the top of the pressure containing body and connecting with a wet-mate optical connector on the same ROV panel

[0027] Figure 7 illustrates WST assembly complete with optical deployment deviceDETAILED DESCRIPTION OF THE INVENTION

[0028] Before the subject invention is further described, it is to be understood that theinvention is not limited to the particular embodiments of the invention described below, as variations of the particular embodiments may be made and still fall within the scope of the appended claims. It is also to be understood that the terminology employed is for the purpose of describing particular embodiments, and is not intended to be limiting. Instead, the scope of the present invention will be established by the appended claims.

[0029] In this specification and the appended claims, the singular forms “a,” “an,” and “the”include plural reference unless the context clearly dictates otherwise. Unless defined otherwise, all technical and scientific terms used herein have the same meaning as commonly understood to one of ordinary skill in the art to which this invention belongs. Unless otherwise specified herein, all materials of construction are preferably steel resistant to the corrosive effects common in oil and gas production environments.

[0030] Turning now to the figures, the present disclosure relates generally to a system andmethod for fiber optic sensing of a subsea well when deployed as part of an overall well stimulation or well intervention system. Figure 1 illustrates a possible system arrangement for connecting hydraulic lines and fiber optic lines between a multi-purpose service vessel (MPSV) and the subsea well upon which the intervention work will occur. The MPSV is outfitted with dynamic positioning capability to hold location during well service operations, offshore lifting and deployment capability, pressure pumping and fluid handling and containment services, and a fiber interrogator to interpret -5 -PD.53614291.1Well Stimulation Optimization and Verification Docket No. P-2149-38368-0007 Customer No.174715 the optical sensing data received from downhole. Installation of a combined hydraulic stimulation and optical sensing device provides the necessary pressure containment and supplemental well control barriers for the reservoir stimulation operations. This device also provides emergency shut- in and disconnect capabilities in the event of a loss of positioning control of the MPSV. Coil tubing lines are suspended from the vessel with clump weights containing the emergency disconnect devices and a fiber optic junction plate. A fiber optic line is also deployed from the vessel and may be attached to a coil tubing line and deployed as part of the coil tubing installation. Hydraulic flying leads are connected by a remotely operated vehicle (ROV) between the subsea ends of the coil tubing and the well stimulation device. The ROV will also connect one end of an optical flying lead to the subsea end of the fiber line deployed from the vessel and connect the other end to the optical sensing deployment device on the stimulation tool. With ROV services in the water to support remote operations, the system is ready to operate.

[0031] Various configurations of the well stimulation, intervention, and optical sensing tool areshown in examples highlighted as Figures 2, and Figures 2a through 2f.

[0032] Before reviewing the different embodiments of the design, it is important to understandthe arrangement of the optical sensing device and the methodology used to retain and deploy the fiber as well as the communication path to the vessel.

[0033] Referring to Figures 3a and 3b, the diagram shows a possible embodiment of such afiber optic sensing deployment device. A connection housing 1 and a pressure containing body 3 provide the main pressure boundary to the well and contains the optical sensing device 6 within the pressure containing body 3. The optical sensing device 6 comprises of a length of optical fiber 7 wound inside or outside of a spool, and the fiber length may be sufficient to reach the bottom of the well at the reservoir. One end of the fiber 7 is connected to the spool with the other end terminated to a connection that is attached and sealed to the pressure containing body 3. This connection 5 receives the optical jumper connector from the coil tubing bulkhead to complete the fiber communication path from downhole to the interrogator unit on the vessel at surface. This deployment device may be individually run on top of a subsea tree or on top of a well stimulation tool (WST) or other well intervention package, hence use of a connector housing, but it can also be directly mounted onto the WST and installed subsea as an integrated multi-function assembly. For purposes of this description, any reference to the WST means either a well stimulation tool or system -6 -PD.53614291.1Well Stimulation Optimization and Verification Docket No. P-2149-38368-0007 Customer No.174715 or any well intervention package (regardless of whether the well intervention package involves stimulation of the well). This provides greater operational functionality and allows reservoir and wellbore data to be collected during flow testing of the well, before and after well stimulation activity to better understand the characteristics of the reservoir before stimulation and to verify successful well performance improvements afterwards. In this instance, the body 3 would be permanently attached and sealed to the well stimulation device, and there would be no connection housing 1 required. After the optical sensing device has been installed subsea and pressure tests completed to verify pressure containment and successful sealing to the subsea tree, the fiber optic jumper is connected between this sensing device and the connection to the fiber optic line deployed from the MPSV vessel. The fiber sensing device within the spool is now ready to be deployed into the well. A retaining device 8 is operated to deploy the fiber spool from the pressure containing body 3 of the fiber optic sensing deployment device 6 and into the wellbore. The device 6 may be operated with ROV assistance, or it may be remotely operated via the well stimulation device, or remotely operated from the vessel.

[0034] Several configurations of this multi-function well stimulation system may be considered.Some, but not all, potential configurations are shown in Figure 2 and Figures 2a through 2f.

[0035] Referring now to Figure 2, this embodiment of the invention has the fiber optic sensingdeployment device 6 mounted directly on top of the main bore through the WST. The connection housing 1 shown in Figure 3 would not be present in this configuration, instead the main body would be attached to the WST body above the two barrier valves. This combined bore through the WST and the fiber optic deployment device 6 provides access into the wellbore for deploying the fiber optic spool, and also provide access for stimulation fluids. This configuration provides an ability to provide hydraulic stimulation and fiber optic sensing of the well before and after stimulation.

[0036] Figure 2a is an alternative arrangement to Figure 2 with similar functionality, but it is aparallel arrangement of optical sensing unit and hydraulic stimulation, instead of in series or coaxially. This configuration allows the additional barrier valves of the WST to be closed, and facilitates flow testing of the well while the fiber optic sensing device 6 is deployed within the well to measure and record flow data, pressure and temperature data and well integrity data amongst other things. -7 -PD.53614291.1Well Stimulation Optimization and Verification Docket No. P-2149-38368-0007 Customer No.174715

[0037] Figure 2b is an alternative arrangement with a similar, in series arrangement as Figure2a, but with a mechanical intervention capability together with hydraulic stimulation. This configuration is well suited to working over horizontal trees where wireline set crown plugs serve as the barrier in production instead of gate valves as in a vertical tree. The mechanical intervention device may be a telescoping connection mounted within a pressure containing housing with two barrier valves mounted below the telescoping device. The telescoping device can be extended and latch onto the upper crown plug within the horizontal tree tubing hanger and remove it from the bore, under well control conditions, and store it within another part of the pressure containing housing for the duration of the stimulation and downhole sensing work. The telescoping device can be deployed a second time to retrieve the lower crown plug and retract it to reside above the barrier valves within the same housing. After the planned stimulation work on the well is complete, the lower and then upper crown plugs can be re-installed and re-tested, before retrieving the complete well intervention device.

[0038] Figure 2c is an alternative arrangement to Figure 2a, offering fiber optic sensingcapability together with mechanical intervention capability. This configuration is well suited to working over horizontal trees where wireline set crown plugs serve as the barriers in production instead of gate valves in a vertical subsea tree. The mechanical intervention device may be a telescoping connection mounted within a pressure containing housing with two barrier valves mounted below the telescoping device. The telescoping device may be extended and latch onto the upper crown plug within the horizontal tree tubing hanger and remove it from the bore, under well control conditions, and store it within another part of the pressure containing housing, away from the well access bore, for the duration of the stimulation and downhole sensing work. The telescoping device can be deployed a second time to retrieve the lower crown plug and retract it to reside above the barrier valves within the same housing. After the planned intervention work on the well is complete, flow testing is completed and the work of the optical sensing device to measure downhole reservoir and well fluid data is complete, the lower and then upper crown plugs can be re-installed and re-tested, before retrieving the complete well intervention device. Alternatively, with a tested surface controlled sub-surface safety valve (SCSSV) and tested lower crown plug in place as two well barriers, the upper crown plug may be removed open water, prior to the WST being deployed. The WST is then landed and locked to the subsea tree and pressure tested. The telescoping device can then simply retrieve the lower crown plug and retract into a position where the plug is located -8 -PD.53614291.1Well Stimulation Optimization and Verification Docket No. P-2149-38368-0007 Customer No.174715 above the two barrier valves, which can then be closed. After the stimulation work and sensing during flow testing has been completed, the barrier valves can be opened, and the lower crown plug re-installed. The WST may then be recovered to surface and the upper crown plug re-installed open water.

[0039] Figure 2d is an alternative arrangement to Figure 2a with similar functionality but isconfigured to allow interventions onto dual bore, eccentric wells. The main difference with this arrangement may be that the intervention device contains an additional body with multiple bores within, to allow intervention onto wells that have separate annulus and production bores, typically offset from the equipment centerline. There may be a device within the connection housing that provides orientation onto the well to provide alignment with the production bore and annulus bore at the top of the subsea tree, together with seal stabs to connect and seal the intervention device to the top of the subsea tree. Alternatively, there may be a bore selector device located within the lower body that allows each of the two bores in the subsea tree, production and annulus access, to be selectively aligned with the intervention tool main bore.

[0040] Figure 2e is an alternative arrangement to Figure 2b with similar functionality but isconfigured to allow interventions onto dual bore, eccentric wells. The main difference with this arrangement may be that the intervention device contains an additional body with multiple bores within, to allow intervention onto wells that have separate annulus and production bores, typically offset from the equipment centerline. There may be a device within the connection housing that provides orientation onto the well to provide alignment with the production bore and annulus bore at the top of the subsea tree, together with seal stabs to connect and seal the intervention device to the top of the subsea tree. Alternatively, there may be a bore selector device located within the lower body that allows each of the two bores in the subsea tree, production and annulus access, to be selectively aligned with the intervention tool main bore.

[0041] Figure 2f is an alternative arrangement to Figure 2c with similar functionality but isconfigured to allow interventions onto dual bore, eccentric wells. The main difference with this arrangement may be that the intervention device contains an additional body with multiple bores within, to allow intervention onto wells that have separate annulus and production bores, typically offset from the equipment centerline. There may be a device within the connection housing that provides orientation onto the well to provide alignment with the production bore and annulus bore -9 -PD.53614291.1Well Stimulation Optimization and Verification Docket No. P-2149-38368-0007 Customer No.174715 at the top of the subsea tree, together with seal stabs to connect and seal the intervention device to the top of the subsea tree. Alternatively, there may be a bore selector device located within the lower body that allows each of the two bores in the subsea tree, production and annulus access, to be selectively aligned with the intervention tool main bore.

[0042] With the above descriptions in mind, the following is a non-limiting outline of preferredor typical operational steps for installation of a multi-function intervention tool (WST) and optical sensor: (1) Fiber line stored within Well Stimulation Tool (2) Well Stimulation Tool locks onto subsea tree (3) Fiber downline deployed via coiled tubing (4) Hydraulic flying leads are connected to the Well Stimulation Tool via coiled tubing (5) Optical flying lead connected to fiber wet-mate on Well Stimulation Tool (6) Well Stimulation Tool and subsea tree barriers pressure testing completed (7) Open Well Stimulation Tool to well and deploy fiber line (8) Use a topside fiber interrogator to get data from the fiber (9) Perform stimulation (10) Perform fiber interrogation once more – post stimulation (11) Close barrier valves and cut fiber; remove Well Stimulation Tool from the subsea tree

[0043] A non-limiting outline typical operational steps for deployment of fiber downhole is asfollows: (1) Fiber is attached to a spool housed inside of WST (2) ROV manually deploys spool, and the fiber unspools as it travels downhole (3) Fiber can be deployed ~25,000 ft (4) Fiber can be pumped if it does not reach required location -10 -PD.53614291.1Well Stimulation Optimization and Verification Docket No. P-2149-38368-0007 Customer No.174715

[0044] As will be understood based on the above descriptions, some of the most useful andadvantageous optical intervention capabilities can include injection profiling, production profiling and monitoring, well integrity, leak detection, and flow assurance.

[0045] As can be understood from the above description and figures, a system and method fordeploying a well intervention system onto a subsea well and deploying a distributed sensing system into the well is provided. The system may provide simultaneous or sequential well intervention activities subsea without recovery or reconfiguration of the equipment. The intervention system may be configured prior to deployment, to provide safe well access for hydraulic, mechanical, or optical intervention operations for multiple different well inspection, remediation, enhancement and / or optimization purposes. The systems and methods described within may be used on concentric bore and dual, eccentric bore subsea systems and may be used on vertical or horizontal trees.

[0046] By combining hydraulic stimulation capabilities with a distributed sensing system, a wellproduction profile may be characterized before stimulation activities to determine stimulation parameters and after stimulation activities to verify stimulation impact and determine performance improvement. Well optimization knowledge and experience can be significantly improved and optimized over multiple well interventions with this additional sensing capability.

[0047] All references cited in this specification are herein incorporated by reference as thougheach reference was specifically and individually indicated to be incorporated by reference. The citation of any reference is for its disclosure prior to the filing date and should not be construed as an admission that the present invention is not entitled to antedate such reference by virtue of prior invention.

[0048] It will be understood that each of the elements described above, or two or more togethermay also find a useful application in other types of methods differing from the type described above. Without further analysis, the foregoing will so fully reveal the gist of the present invention that others can, by applying current knowledge, readily adapt it for various applications without omitting features that, from the standpoint of prior art, fairly constitute essential characteristics of the generic or specific aspects of this invention set forth in the appended claims. The foregoing embodiments are presented by way of example only; the scope of the present invention is to be limited only by the following claims. -11 -PD.53614291.1

Claims

Well Stimulation Optimization and Verification Docket No. P-2149-38368-0007 Customer No.174715 CLAIMS The invention claimed is:

1. A system for providing safe well access for hydraulic, mechanical, and optical interventionoperations to increase performance of a reservoir formation, comprising:a deployment package that is a marinized assembly, comprising: (a) a connection housing for connecting the deployment package to a subsea tree, wherein the connection housing has one or more bores to access a well; (b) one or more well intervention modules attached to the connection housing that are configured to access the well; (c) fluid connection path to the well having one or more barrier valves; (d) a first access opening to the well with one or more barrier valves; and (e) a second access opening to the well for deploying an optical fiber system, wherein the optical fiber system comprises: (i) a deployable device retained within the housing; (ii) one or more downhole sensing fibers connected on one end to the deployable device; (iii) a connection to an opposite end the downhole sensing fibers to provide communication to an optical jumper located external to the deployment package; and (iv) a retaining device configured to retain the deployable device within the housing during subsea installation and to deploy it into the wellbore.

2. The system of claim 1, wherein the well intervention modules comprise an optical fiber deployment device positioned horizontally adjacent to a hydraulic stimulation tool to provide independent access to the well for successive or concurrent operations.

3. The system of claim 1, wherein the well intervention modules comprise a hydraulic stimulation tool positioned horizontally adjacent to a mechanical intervention device configured to retrieve and re-install crown plugs into a horizontal tree bore.

4. The system of claim 1, wherein the well intervention modules comprise an optical fiber deployment device positioned horizontally adjacent to a mechanical intervention device configured to retrieve and re-install crown plugs into a horizontal tree bore. -12 -PD.53614291.1Well Stimulation Optimization and Verification Docket No. P-2149-38368-0007 Customer No.174715 5. The system of claim 1, wherein the well intervention modules comprise an optical fiber deployment device positioned horizontally adjacent to a hydraulic stimulation tool to provide independent access to the well for successive or concurrent operations, and further configured to access a dual-bore eccentric completion system.

6. The system of claim 1, wherein the well intervention modules comprise a hydraulic stimulation tool positioned horizontally adjacent to a mechanical intervention device configured to retrieve and re-install crown plugs into a horizontal tree bore, and further configured to access a dual-bore eccentric completion system.

7. The system of claim 1, wherein the well intervention modules comprise an optical fiber deployment device positioned horizontally adjacent to a mechanical intervention device configured to retrieve and re-install crown plugs into a horizontal tree bore, and further configured to access a dual- bore eccentric completion system.

8. A method for providing safe well access for hydraulic, mechanical, and optical intervention operations to increase performance of a reservoir formation, comprising: (a) providing a deployment package that is a marinized assembly, comprising: (i) a connection housing for connecting the deployment package to a subsea tree, wherein the connection housing has one or more bores to access a well; (ii) one or more well intervention modules attached to the connection housing that are configured to access the well; (iii) fluid connection path to the well having one or more barrier valves; (iv) a first access opening to the well with one or more barrier valves; (v) a second access opening to the well for deploying an optical fiber system, wherein the optical fiber system comprises: (1) a deployable device retained within the housing; (2) one or more downhole sensing fibers connected on one end to the deployable device; (3) a connection to an opposite end the downhole sensing fibers to provide communication to an optical jumper located external to the deployment package; and -13 -PD.53614291.1Well Stimulation Optimization and Verification Docket No. P-2149-38368-0007 Customer No.174715 (4) a retaining device configured to retain the deployable device within the housing during subsea installation and to deploy it into the wellbore; (b) operating the optical fiber system to detect conditions of the well and the performance of the reservoir; (c) operating the well intervention modules to improve the conditions of the well and increase the performance of the reservoir; and (d) after the step of well intervention has been completed, operating the optical fiber system to detect conditions of the well and the performance of the reservoir.

9. The method of claim 8, further comprising the step of injecting one or more additional fluids into the reservoir to improve the ability of the optical fiber system to characterize the performance of the reservoir.

10. The method of claim 9, where the one or more additional fluids includes a gel adapted to enhance fluid coupling.

11. The system of claim 8, further comprising the step of applying a percussive force sufficient to establish an acoustic signal transmitted downhole as a reference signal for the optical fiber system in detecting reflections from the reservoir. -14 -PD.53614291.1

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