![]() ![]() Also, the reciprocating pump and charge pump are not isolated. When the standpipe is installed on the suction manifold’s deadhead side, there’s little opportunity to get fluid into all the cylinders to prevent cavitation. The thought behind this design was to create a gas-over-fluid column for the reciprocating pump and eliminate cavitation. I’ve run into several instances of insufficient suction stabilization on rigs where a “standpipe” is installed off the suction manifold. The design ultimately caused cavitation issues and premature pump expendable failure resulting in unplanned repairs and downtime. Isolating pumps are crucial in piping design to limit the negative impacts of compounding signatures.įor example, I’ve seen a rig piping design where both reciprocating pumps were feed through a single supply line, exposing both pumps to each others’ mechanical and acoustic signatures as well as the charge pump. Installing an individual supply line for each mud pump ensures pumps have adequate fluid to prevent cavitation. Solution: Feed Each MP with an Individual Supply Line Often “pump chatter” from a reciprocating pump occurs without a proper suction stabilizer installed and is usually limited to a charge pump. ![]() “Pump chatter” occurs when reciprocating pumps have the opportunity to interact with other pumps. The net result is “pump chatter,” a water hammer effect, and a supply choke for the secondary pump with high flow rate requirements. ![]() With a single feed design, fluid deprivation often occurs at the second pump. It’s common for older rig designs to see a single supply line installed for two mud pumps. The good news is older mud systems can be modified to meet the aggressive targets of today’s horizontal and directional drilling plan contracts.īelow are five common operational efficiency challenges I’ve encountered in working on contractor rig consults and suggested solutions to optimize a mud system’s performance, efficiency, and ultimately contractors’ long term profitability. The net result is significant profit loss due to delayed drill plan completion and loss of potential prospective contracts due to drilling plan goals not being achieved. Besides, aging systems require frequent maintenance and often encounter unexpected repairs that increase unplanned downtime. The downside of operating dated mud systems can be significant decreases in performance, efficiency, and safety. These are essential to handle the 7500 psi and up to 1400 BPM rates needed to achieve the aggressive drill plans of today and beyond. As an oil and gas industry pulsation control specialist, I’ve consulted with many contractors in numerous US shale plays about optimizing mud systems on older rigs to achieve maximum performance and profitability.Ī common challenge in consults with contractors is, many older rigs built in the pre-fracking era have mud systems lacking appropriate piping size, pulsation control technology, and structural design. ![]()
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