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BR-112021009227-B1 - HIGH FLOW RATE FORMATION APPARATUS, SYSTEM, AND TEST METHOD

BR112021009227B1BR 112021009227 B1BR112021009227 B1BR 112021009227B1BR-112021009227-B1

Abstract

HIGH-FLOW FORMATION TESTING APPARATUS, SYSTEM, AND METHOD. The formation testing apparatus consists of an upper assembly, an impeller unit, a cradle packer unit, and an inverted reservoir description tool string. The upper assembly seals the steel cable on the platform and connects the steel cable to the formation testing apparatus. The impeller unit includes an upper turbine that converts the hydraulic power of the drilling mud circulation into mechanical power. The mechanical power is used to drive a lower impeller that is capable of pumping formation fluids at high flow rates. The cradle packer unit isolates a portion of the formation testing apparatus that is open in the wellbore to allow the inflow and outflow of formation fluids through the formation testing apparatus. The inverted reservoir description tool string contains a combination of formation description modules that are inverted from traditional reservoir description tool modules to allow flow paths to bypass electrical components.

Inventors

  • Edward Harrigan
  • MATTHEW L. LEE
  • AMEET B. AGNIHOTRI
  • CHARLES WILTON SECKAR
  • CHRISTOPHER MICHAEL JONES
  • NESTOR JAVIER RODRIGUEZ
  • DARREN GEORGE GASCOOKE

Assignees

  • HALLIBURTON ENERGY SERVICES, INC

Dates

Publication Date
20260310
Application Date
20200717
Priority Date
20200716

Claims (15)

  1. 1. High flow rate formation testing apparatus, characterized in that it comprises: an upper assembly (110); an impeller assembly (120) connected to a lower portion of the upper assembly (110), wherein the impeller assembly (120) comprises a first impeller (121A) connected to a second impeller (121B) via a shaft (123) located longitudinally within the apparatus; a first flow line (135) comprising a first end having an opening for a well (503); a packing device that isolates a portion of the well around the first end of the first flow line (135) from the rest of the well (503); and a tool string (140) connected to the first flow line (135), wherein the tool string (140) hydraulically connects the packing device to the upper assembly (110).
  2. 2. Apparatus according to claim 1, characterized in that the tool column (140) further comprises modules for analyzing fluid formation properties, wherein the modules comprise at least one of a pump (141), a fluid identification module (142), a module for storing sample chambers (143), a reservoir description module, a power and telemetry module (144, 145) and an inverted wire rope profiling head.
  3. 3. Apparatus according to claim 1 or 2, characterized in that the first impeller (121A) transfers mechanical power to operate the second impeller (121B) through the shaft (123).
  4. 4. Apparatus according to claim 3, characterized in that it comprises: a valve (133) located along the first flow line (135) between the first end and the second impeller (121B) to control a flow rate of the formation fluid based on mechanical power; and a valve (138) located along a second flow line (139) connected to the first flow line (135) to isolate the formation fluid in an area of the apparatus, wherein the first flow line (135) has a larger diameter than the second flow line (139) and wherein the larger diameter allows greater fluid circulation.
  5. 5. Apparatus according to any one of claims 1 to 4, characterized in that it further comprises valve(s) for inflating the packing device to isolate the portion of the well (503) around the first end of the first flow line (135) from the rest of the well (503).
  6. 6. Apparatus according to any one of claims 1 to 5, characterized in that it further comprises a gauge (136) for monitoring the formation fluid pressure of the isolated portion of the well (503).
  7. 7. High-flow formation testing system for an apparatus as defined in claim 1, characterized in that it comprises: a pipe string; a steel cable (508) passing through the pipe string; and a downhole tool for formation testing, wherein the downhole tool comprises: an upper assembly (110), an impeller assembly (120) connected to a lower portion of the upper assembly (110), wherein the impeller assembly (120) comprises a first impeller (121A) coupled to a second impeller (121B) by a shaft (123), a first flow line (135) having a first end that is open to the formation, a packing device that isolates a portion of a well (503) around the first end of the first flow line (135) from the rest of the well (503); a tool column (140) connected to the first flow line (135), wherein the tool column (140) hydraulically connects the packing device to the upper assembly (110).
  8. 8. System according to claim 7, characterized in that the tool column (140) further comprises modules for analyzing formation fluid properties, wherein the modules comprise at least one of a pump (141), a fluid identification module (142), a module for storing chambers and retrieving fluid samples, a reservoir description module, a power and telemetry module (144, 145) and an inverted wire rope logging head.
  9. 9. System according to claim 7 or 8, characterized in that the steel cable (508) is connected to the upper assembly (110) by means of a wet connection lock (114), and in that the drive assembly (120) comprises electrical connections suitable for routing the steel cable (508) to the tool column (140).
  10. 10. System according to any one of claims 7 to 9, characterized in that the first impeller (121A) transfers mechanical power to operate the second impeller (121B) through the shaft (123) which is located longitudinally within the downhole tool.
  11. 11. System according to any one of claims 7 to 10, characterized in that it further comprises: a valve (133) along the first flow line (135) between the first end and the second impeller (121B) for controlling a flow rate of formation fluid based on mechanical power; and a valve (138) along a second flow line (139) connected to the first flow line (135) for isolating the packing device from the rest of the downhole tool and the wellbore, wherein the first flow line (135) has a larger diameter than the second flow line (139) and wherein the larger diameter produces a lower pressure drop to allow greater fluid circulation.
  12. 12. System according to claim 11, characterized in that it further comprises a third flow line connected to the packing device by means of a valve for inflating the packing device, wherein a diameter of the third flow line is smaller than a diameter of the first flow line and wherein the third flow line branches off from the first flow line (135).
  13. 13. High flow rate formation test method implemented by a system as defined in claim 7, characterized in that it comprises: circulating drilling fluid in an annular space of a downhole tool, wherein the hydraulic power of the circulated drilling fluid generates torque of a first impeller (121A) of a flow rate formation test device; wherein the torque from the first impeller (121A) drives a second impeller (121B); and extracting formation fluids to flow lines (135, 139) of the flow rate formation test device from the drive of the second impeller (121B).
  14. 14. Method according to claim 13, characterized in that it further comprises collecting samples of the formation fluid as the formation fluid is extracted through the flow lines (135, 139).
  15. 15. Method according to claim 13 or 14, characterized in that it further comprises: recording a pressure response to a dynamic change in the flow rate of the extracted formation fluid to the flow lines (135, 139) of the flow rate formation test device; and analyzing the pressure response.

Description

TECHNICAL FIELD [001] Disclosure generally refers to the field of earth or rock drilling and equipment for testing underground formation fluids, pressures and formation fluid communication between and within zones and pores of underground formations. FUNDAMENTALS [002] Formation testing helps characterize a formation around a well by measuring pressure dynamics in response to flow, capturing formation fluid samples, determining the oil or gas composition in a formation, estimating the formation's oil and gas recovery potential, estimating the size of the fluid-bearing formation, and/or estimating the connectivity of different formations within the well or between wells. Formation testing can be performed throughout many phases of a well's life, such as exploration, development, production, and injection stages. Drill string tests (DSTs) are a type of formation test that are typically performed soon after a well has been drilled into the formation. DST systems characterize reservoir flow and detect bed boundaries in the formation. A DST tool is placed near a zone of interest, and the wellbore is sealed above and below the DST tool to analyze well flow and pressure. The information obtained from a DST can be used to estimate reserves, optimize reservoir development, and maximize production. A typical DST requires one to two weeks of platform time to obtain measurements. BRIEF DESCRIPTION OF THE DRAWINGS [003] The methods of disclosure can be better understood by reference to the attached drawings. [004] FIG. 1 is a schematic view of a high-flow forming test device. [005] FIG. 2 is a high flow rate formation test device with additional pressure gauges for vertical interference testing. [006] FIG. 3 is a flowchart of operations for formation testing using transmitted energy from the surface using a two-part impeller unit in a high-flow formation testing device. [007] FIG. 4 represents a flowchart of operations for power generation using a two-part impeller unit. [008] FIG. 5 represents an example of a well with a pipe-carried high-flow formation testing device. [009] FIG. 6 is an example system for training testing. DESCRIPTION OF THE MODALITIES [0010] The following description includes example systems, methods, techniques, and program flows that constitute embodiments of the disclosure. However, it is understood that this disclosure can be practiced without these specific details. For example, this disclosure refers to high-flow formation testing devices onshore in illustrative examples. Embodiments of this disclosure can also be applied to offshore platforms and subsea wellbore drilling. In other examples, well-known instructional examples, protocols, structures, and techniques have not been shown in detail in order not to obscure the description. Overview [0011] Formation testing can involve the use of many types of measurement tools to characterize reservoirs. Drill string testing (DST) tools are used to determine the productive capacity and permeability of a formation by characterizing reservoir flow and detecting bed boundaries of interest tens or even hundreds of meters away from the wellbore. However, obtaining information from DSTs generally requires one to two weeks or more of expensive rig time. Wire rope formation testing (WFT) tools are another option for conducting in-situ formation testing. While WFTs require less rig time, existing WFT tools have limited reservoir flow rates (typically less than 1 gal/min) due to electrical limitations associated with power transmission via wire rope, the energy efficiency of downhole technology, and the difficulty of dissipating heat generated by pumps and motors in the wellbore. As a result, WFTs typically have a shallow reservoir investigation depth. Formation testing tools "during drilling," such as metering-drilling (MWD) or logging-drilling (LWD) tools, are another characterization tool. These tools often use turbines to generate electrical power at the bottom of the hole, which can be used to drive a pump at the bottom of the hole. However, the efficiency of these systems limits the maximum pumping power available, and the heat dissipated by the electromechanical systems is difficult to dissipate in the wellbore. Each of these formation characterization tools provides valuable information but can incur significant costs in terms of time, money, and efficiency. [0012] A formation testing system (FTS) is disclosed that performs DST operations using a WFT tool and a drill pipe delivery tool push system. The FTS incorporates a cable-deployed high-flow formation testing device. A drill pipe delivery tool push system, in which a drill pipe connects to an upper portion of the WFT tool, assists in moving the tool down the wellbore. This provides control over tool location in horizontal and highly deviated wells, prevents the tool string from becoming stuck in the wellbore with cable deployment, provides a means of distributing energy and cooling to downhole tools