High capacity (10 GW, for example) passively cooled non-superconducting underground high voltage direct current electric power transmission lines (100) of very low loss (1% per 1,000 km, for example) and competitive cost. The transmission lines (100) include segment modules (101) linked together with compliant splice modules (102) between the segments (101), typically installed in a protective conduit (103). The segment modules (101) include relatively rigid pipe-shaped conductors (117) insulated by pipe-like solid insulating layers (131) to form segment modules (101) that resemble pipe. The segment modules (101) are linked together through radially and axially compliant splice modules (102) to form the transmission line (100). There are preferably wheels (300) deployed to ease insertion and removal of the assembled segment modules (101) and splice modules (102) into the conduit (103), to center each segment module (101) within the conduit (103), and/or to provide motive force and/or braking to allow the assembled segment modules (101) and splice modules (102) to be installed on a slope.

An article includes a cold-shrinkable protective housing configured to be mounted on a terminated cable. The protective housing includes a housing body and an integral, tubular, electrically insulating rejacketing sleeve. The housing body includes a tubular cable leg, a tubular connector leg extending transversely to the cable leg, and a housing insulation layer formed of an electrically insulating elastomer. The rejacketing sleeve surrounds a portion of the cable leg. The connector leg defines a connector bore. The cable leg defines a cable entrance opening at a proximal end and a cable receiving bore extending from the cable entrance opening to the connector bore at a distal end. The cable receiving bore extends transversely to the connector bore. The rejacketing sleeve includes an extension section configured to extend or be extended in a proximal direction beyond the proximal end of the cable leg to surround a jacket of the cable.

An article includes a cold-shrinkable protective housing configured to be mounted on a terminated cable. The protective housing includes a housing body and an integral, tubular, electrically insulating rejacketing sleeve. The housing body includes a tubular cable leg, a tubular connector leg extending transversely to the cable leg, and a housing insulation layer formed of an electrically insulating elastomer. The rejacketing sleeve surrounds a portion of the cable leg. The connector leg defines a connector bore. The cable leg defines a cable entrance opening at a proximal end and a cable receiving bore extending from the cable entrance opening to the connector bore at a distal end. The cable receiving bore extends transversely to the connector bore. The rejacketing sleeve includes an extension section configured to extend or be extended in a proximal direction beyond the proximal end of the cable leg to surround a jacket of the cable.

A cable accessory device (2) comprises an outer body (6) having a first side (8), a second side (10), and an interior space (12); a stress controlling element (14), and an inner layer (28). At least the first side (8) is configured to feed an end of a high voltage cable (4) into the interior space (12). The stress controlling element (14) is configured to be arranged on the cable (4). The inner layer (28) is configured to be arranged around the cable (4) under tension. At least one pressure alleviating component (20) having a first end (24) and a second end (26) is configured to be placed around the cable (4) at the stress controlling element (14) or the inner layer (28) to exert a radially inwards directed force onto the cable (4), the force decreasing from the first end (24) to the second end (26).

A cable accessory device (2) comprises an outer body (6) having a first side (8), a second side (10), and an interior space (12); a stress controlling element (14), and an inner layer (28). At least the first side (8) is configured to feed an end of a high voltage cable (4) into the interior space (12). The stress controlling element (14) is configured to be arranged on the cable (4). The inner layer (28) is configured to be arranged around the cable (4) under tension. At least one pressure alleviating component (20) having a first end (24) and a second end (26) is configured to be placed around the cable (4) at the stress controlling element (14) or the inner layer (28) to exert a radially inwards directed force onto the cable (4), the force decreasing from the first end (24) to the second end (26).

The present invention relates to a splice connection system for securely connecting electro submersible pump cables that transmit power from an external source to downhole equipment in an underground well for oil extraction applications, thereby ensuring enhanced durability, reliability, and ease of assembly in harsh well environments. The splice connection system comprises a pair of ESP cables and a spliced enclosure. The spliced enclosure comprises seal bands, sealing rings, seal members, splice connectors, a protective case, a potting insulation compound, an epoxy sealant and reinforced housing. The splice connection system significantly reduces installation time and complexity compared to traditional methods by providing a secure, efficient, and resilient splicing approach, thereby improving overall reliability of ESP systems. The splice connection system simplifies the splicing process, minimizes waste, and enhances performance and longevity of ESP cable connections.

An automated workflow for processing dual arrival events consisting of: (1) an automated time pick that located and characterized dual compressional and shear arrival events present in acoustic waveform measurements; and (2) a ray tracing inversion procedure that inverted these time picks and constructed a locally layered formation model of slowness along the well trajectory. The disclosed workflow embodiments provide the following benefits: (1) an automated time pick which estimates the variation of the arrival event with measured depth and determines whether the shoulder bed is above or below the well track; and (2) a ray tracing inversion that determines the raypath type of the dual arrival event. The disclosed workflow embodiments provide a log display of tool layer and shoulder bed compressional and shear slowness which is useful for making correct porosity, VP/VS, and Poisson ratio estimates as well as other geomechanics answers.

An automated workflow for processing dual arrival events consisting of: (1) an automated time pick that located and characterized dual compressional and shear arrival events present in acoustic waveform measurements; and (2) a ray tracing inversion procedure that inverted these time picks and constructed a locally layered formation model of slowness along the well trajectory. The disclosed workflow embodiments provide the following benefits: (1) an automated time pick which estimates the variation of the arrival event with measured depth and determines whether the shoulder bed is above or below the well track; and (2) a ray tracing inversion that determines the raypath type of the dual arrival event. The disclosed workflow embodiments provide a log display of tool layer and shoulder bed compressional and shear slowness which is useful for making correct porosity, VP/VS, and Poisson ratio estimates as well as other geomechanics answers.

Systems and methods are provided for improved installation speed and reliability for mechanical cable splices to safely retrieve an armored electrical cable and attached electrical submersible pump (ESP) from a wellbore. The ESP can be brought to the surface for replacement or maintenance and reinstallation along with the same armored power cable. Embodiments of cable splice devices are provided to establish a strong splice having tensile strength required or exceeding that needed to retrieve the cable and ESP from the wellbore safely. A bypass load-bearing clamp may be used temporarily to further assist the tensile strength of the cable non-electrical splice if such tensile strength is deemed insufficient to safely overcome the required retrieval forces. Furthermore, the splice includes a short-circuit electrical connector that enables a quick electrical continuity test for determining if the cable is suitable for redeployment.

Systems and methods are provided for improved installation speed and reliability for mechanical cable splices to safely retrieve an armored electrical cable and attached electrical submersible pump (ESP) from a wellbore. The ESP can be brought to the surface for replacement or maintenance and reinstallation along with the same armored power cable. Embodiments of cable splice devices are provided to establish a strong splice having tensile strength required or exceeding that needed to retrieve the cable and ESP from the wellbore safely. A bypass load-bearing clamp may be used temporarily to further assist the tensile strength of the cable non-electrical splice if such tensile strength is deemed insufficient to safely overcome the required retrieval forces. Furthermore, the splice includes a short-circuit electrical connector that enables a quick electrical continuity test for determining if the cable is suitable for redeployment.