Recently, testing has been made up of a combination of flow and shut-in periods and with greater complexity for well testing providing greater accuracy for volumes and understanding.
Well testing is typically performed by directing well production through a three-phase separator as indicated in figure 1 or if hydrocarbon liquids are too small to be measured during typical well test durations then a two-phase separator may be used. For orifice meters, the test gas meter must use hour charts for a test period of 72 hours or less, unless electronic flow measurement is used; for testing periods longer than 72 hours, 7-day charts may be used, provided that good, readable pen traces are maintained see section Directive 4.
Business processes and field level procedures often introduce significant business risk; specifically with respect to regulatory compliance and enforcement, business reputation and potential financial loss. Some financial impacts of improper testing may result in:. After performing high-quality well tests, companies must follow the technical procedures listed in AER requirements. When each test is over, they are required to submit the results for regular compliance with Directive , , If you are seeking well testing services, consider an energy services provider such as Intricate with their leading expertise and equipment to get the job done.
Intricate has designed, manufactured and fully integrated an automated gas production testing solution for conventional and heavy oil production facilities. Operators use AOF as the basis for calculations to determine the relationship between backpressure settings and flow rates of the well. Rather than use well tests, operators may opt to evaluate their wells using wireline formation testers that include a quartz pressure gauge and a fluid sampling tool placed across a production interval Figure 2.
During these formation tests, reservoir fluids are pumped or flowed into the wireline formation tester through a probe inserted into the formation or between packers set above and below the sampling site. Figure 2. Wireline formation tester sampling. Pistons are driven from one side of the wireline formation tester to force a packer assembly firmly against the formation to be tested.
At its center, the packer includes a probe that is then extended into the formation to withdraw wellbore fluids. Formation fluids red arrows flow into the probe and into flow lines. The fluids are pumped into the wellbore until they are sufficiently free of contamination as determined by downhole fluid analysis green and brown cylinders.
Uncontaminated fluids are directed into storage bottles orange where the fluids are kept at in situ conditions. Multiple samples can be taken on one trip into the well. When all tests are completed, the samples are brought to the surface and may be sent to laboratories for advanced testing. A quartz pressure gauge measures and records bottomhole pressures. The reservoir fluids, which may be contaminated with drilling fluid, are first flowed or pumped through flowlines in the tool into the wellbore while the contamination level decreases.
Once engineers determine that the formation is delivering minimally contaminated reservoir fluids, they redirect flow to sample chambers within the tool. The chambers are retrieved to the surface and transported to laboratories for analysis. Scientists also use downhole fluid analysis DFA to monitor the sampling process. Using optical spectroscopy, or the recorded light spectrum, engineers identify in real time the composition of fluids as they flow into the tool; this method also reveals critical data about the reservoir without waiting for laboratory tests to be completed.
Additionally, the DFA measurements confirm that the sample is uncontaminated and eliminate uncertainties associated with fluid transport and laboratory reconstruction of in situ conditions necessary for fluid analysis.
A variety of well and formation test schemes are performed throughout the stages in the life of a well or field. At the exploration stage, operators may use well tests to simulate production after a well is completed to establish production potential and reserves estimates.
In addition, capturing large fluid samples at the surface gives experts an opportunity to perform laboratory measurements on the reservoir fluids. Well tests at the exploration stage also allow operators to determine if low flow rates are affected by skin or are the result of natural permeability of the reservoir. Armed with the knowledge of either situation, engineers can then take appropriate actions, plan treatments that may be necessary once production commences or decide to abandon the project for economic reasons.
For instance, well tests can be used to estimate reservoir size, which allows operators to abandon a small reservoir that will not be economical despite high initial flow rates. During the field development stage, well tests help indicate wells that may require stimulation treatments. Using well test data, engineers predict induced or natural fracture length and conductivity. They can then estimate productivity gains that may be realized from a stimulation treatment. In addition, wireline formation testers can be used for pressure testing to determine static reservoir pressures and to confirm fluid contacts and density gradients.
This information helps analyze communication within the reservoir, tie reservoir characteristics to a geologic model and identify depleted zones. During the production phase, well tests are aimed at monitoring reservoirs, collecting data for history matching —comparing actual production with predicted production from reservoir simulator—and assessing the need for stimulation.
These tests use a pressure gauge placed at formation depth to collect data during pressure buildup and drawdown. Well productivity usually diminishes over time, sometimes as a result of formation damage from fines migration —the movement of very small particles through the formation to the wellbore where they fill pore spaces and reduce permeability.
Engineers may perform formation tests to predict the likely effectiveness of treatments to remove these fines. The effects of completion choices may also be assessed using formation tests to aid engineers in planning required remedial operations. Qualifications To perform this job successfully, an individual must be able to perform each essential duty satisfactorily. Strong communication and customer service skills. Energy service experience helpful.
Exhibit ability to be a strong team player. Possess excellent written and verbal skills, as well as excellent interpersonal skills. Ability to manage multiple projects in an environment of constantly changing priorities. Ability to work independently. Physical Demands Ability to lift lbs. Ability to work in all types of weather conditions.
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