The Precision Choice for Well‑Completion Metering: Engineering Practices with Closed‑System Metering Tanks
Sealed metering tanks are typically designed as vertical or horizontal cylindrical vessels, with operating pressures ranging from 0.5 MPa to 6.4 MPa and capacities varying from 5 m³ to 50 m³. The tank top is equipped with a nitrogen or natural gas pressure‑replenishment port, while the bottom features a liquid outlet pipe and cleaning/drainage ports. The core measuring components consist of two independent level‑sensing systems: one is a hydrostatic differential pressure transmitter, and the other is a guided wave radar or a magnetic flip‑plate local indicator. These two systems are cross‑calibrated to eliminate single‑instrument errors caused by fluctuations in medium density or foam layers. An external insulated jacket is welded onto the tank body to maintain the fluidity of high‑pour‑point completion fluids.
In field operations, metering tanks are often connected in series with fracturing trucks or coiled‑tubing units. For example, prior to an acidizing treatment, a predetermined volume of acid is pumped into the tank; as pumping continues, the rate of liquid level decline is recorded to estimate the actual flow rate, which is then compared with the pump stroke count to calibrate pump efficiency. During the flowback phase, the volume of produced fluids is collected, and by analyzing chloride ion titration and pH changes, one can assess formation water production or the extent of acid–rock reactions. To ensure data reliability, a “zero‑point calibration” must be performed before each measurement: after closing the inlet and outlet valves, maintain pressure for 5 minutes and monitor whether the liquid level drifts. If the drift exceeds ±0.5%, the transmitter’s zero point or tank leakage should be investigated.
The main factors affecting measurement accuracy include: pressure fluctuations caused by variations in the gas-phase temperature inside the tank (requiring the implementation of a temperature-compensation algorithm); residual gas bubbles in the liquid‑discharge pipeline (necessitating the installation of a gas‑collection header at the tank bottom for periodic venting); and solid deposits adhering to the tank walls (which should be removed after each well by circulating hot water or solvent). Operational procedures mandate recording level, pressure, and temperature every half hour and plotting volume‑time curves. In the event of an abrupt drop or sharp rise, the status of surface valves must be verified immediately to prevent mistakenly treating the tank as a conventional storage vessel. Although closed‑system metering tanks are structurally simple, their data directly inform completion decisions—accurate volumetric accounting translates into efficient operational performance.
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A sealed metering tank is a pressurized vessel used in well completion and workover operations to accurately measure the volume of fluids entering the wellbore or returning to the surface, serving simultaneously as a storage unit, a metering device, and a buffer. Its fully enclosed design prevents the loss of volatile components—such as light hydrocarbons or acidic fluids—while enabling real-time volume readings via differential pressure or radar level gauges, thereby providing essential data for evaluating acidizing and fracturing performance, calculating formation fluid intake, and determining flowback rates. This paper outlines its structural features, factors influencing measurement accuracy, and operating procedures.
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Purification Slurry Dynamics — The Technical Value of Iron-Removal Equipment for Drilling Mud
Mud‑iron removal equipment is a specialized purification unit within the solid‑control system of drilling fluids, designed to eliminate both magnetic and nonmagnetic ferrous particles generated during mud circulation due to drill‑bit wear, formation abrasion, and pipe‑wall corrosion. If these fine iron particles are not promptly removed, they can exacerbate abrasive wear on pump pistons, cylinder liners, and the inner walls of hydrocyclones, while also interfering with the magnetic signals of logging‑while‑drilling tools. This paper presents the equipment’s magnetic separation principle, the criteria for selecting it, and the methods used to verify its performance.
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Systematic Application of the Choke and Kill Manifold: The Core of Well Control Barriers
The choke and kill manifold is a critical surface‑level flow‑control system used in drilling and workover operations to actively manage wellbore pressure. By combining adjustable flow valves with multi‑port manifolds, it enables precise release of downhole fluids during shut‑in and kill procedures, maintaining bottomhole pressure slightly above formation pressure and thereby preventing overflow from escalating into a blowout. This paper analyzes its structural principles, operational logic, and key maintenance considerations.
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