Wells well.Some well heads have wireless load cells

Wells operated without supervision can always be faulty using too much power or losing capacity this generally causes lower performance and therefore higher maintenance and operations costs. In some cases the oil reservoir may run dry therefor continuous monitoring of the oil well and the oil field equipment is essential to ensure there is a reliable supply and optimum performance.This system will audit and control the elements that influence the well’s performance in real time. This checks on hydraulic variables such as flow, pressure or even level and the data can be accessed locally via the pc or remotely online. When the system detects any abnormal conditions, alarms will be triggered and sms notifiactions will be sent to the maintenance personnel who can the address the issues. Furthermore, periodic performance reports makes this system a powerful predictive tool essential for the planning of predictive maintenance and also early preparation of processes such as hydraulic fracking to boost the production of the oil well.Some well heads have wireless load cells which are solar powered, wireless digital communication, u-shape structure and transmits there data to the wireless receiver on the ground which sends the data to the pc.Demanding energy economics require more efficient oil well drilling operations such that the mud engineers, mud-loggers, drillers, geologists and Measurement While Drilling (MWD) engineers can have real time information exchange between the rig site and the command centres. This requires costly and complex hardware and software infrastructure. Therefore, in order to have real-time access to key drilling nd evaluation pararmeters where one can make informed decisions on the spot, maximize the economic value of the operations and minimize risks through real time view of drilling operations, the next generation MWD-LWD surface system was developed. This enabled digital oilfield efficiencies and cost saving with real-time view of operations by getting data on demand anytime, anywhere with no need of additional hardware or software. It is a web-based application with a user friendly interface compatible with any HTML 5 web-browser. This enables remote monitoring and diagnostics. This proposed system will ensure high reliability and accuracy by using the raw data recording which allows playback and recalculation while still in-hole.  It will also enable multiple users to get access to the data concurrently.The system can be updated automatically while running whenever connectivity is established hence with no downtime needed to install updates.P an t are collected at each installation point Installing casing conveyed permanent down-hole monitoring system gives betters accuaray in correlating reservoir pressure to injection and production pressure at the well head. This results in better predctions, monitoring and evaluation of project performance. PDM uses a combination of sensoes attached to the outside of the well casingto provide a rich source of data without interfering with production and injection activities. The heart of the PDM system is sensors that record temperature and pressure and relay the data to a data logger in the surface. The system is made up of two types of monitors. The first is the distributed temperature system (DTS) which is a fibre optic line that runs the entire length of the casing which monitors temperature every metre thus providing a profile of temperature from the bottom of the well to the surface. The second system consists of pressure temperature gauges fastened at discrete levels along the outside of the casing string. The PT gauges are connected to each other and to the surface data logger through a multi-conductor armory cable similar to a wireline logging cable. Pressure and temperature data are collected at each installation point. The pressure gauge must have direct access to the fluids at the surrounding formations to measure pressure effectively. This occurs in one of two ways: Initially, access is achieved through a pore in a pressure pad located several feet below the gauge connected via a cord and stainless steel capillary tube. This port sits against the borehole wall and measures the