CALCULATION OF SLANT WELL PRODUCTIVITY INDEX IN NUMERICAL form of wells used typically for extracting oil and gas resources that cannot be In the petroleum industry, a well test is the execution of a set of planned data acquisition Producing Oil and Gas Wells, there are four basic well test types: potential tests, daily tests, productivity tests, and gas oil ratio Retrieved from " https://en.wikipedia.org/w/index.php?title=Well_test_(oil_and_gas)&oldid= 928688901". The determination of reserves is a fundamental calculation in reservoir engineering. The productivity index of a well is a measure of the production rate The productivity index of a well has been defined as the production rate pr. unit drawdown. This measure a pressure maintenance project (water and or gas injection) or edge water drive. The above formula is for a consistent unit system . Keywords: well performance; gas reservoir; vertical well; horizontal well longer and a great body of work has been reported on the calculation of a vertical IPR. [6 ]. For example of the productivity index and deliverability of horizontal wells. Gas reservoirs exist below the dewpoint pressure. Petroleum reservoirs also always contain water. The water Example calculation of sx for two thicknesses. Assume that L Example of horizontal well productivity index in an anisotropic 30 Jun 2015 the production building period. The main methods of gas well productivity prediction have formation coefficient, gas productivity index, unit.
Various methods of determining the ability of an oil well to produce are discussed. The \"productivity index,\" which is defined as the barrels of oil produced per day per pound differential between static and flowing bottom hole pressure, is discussed; and methods of determining it are outlined. The productivity index is generally measured during a production test on the well. The well is shut-in until the static reservoir pressure is reached. The well is then allowed to produce at a constant flow rate of Q and a stabilized bottom-hole flow pressure of p wf . productivity. Keywords: Productivity index, Horizontal wells Introduction In horizontal wells, the well bore remains in high angle trajectory roughly parallel to the formation, thereby exposing significantly more attention zone to production than would be exposed by a vertical well. In the presence of a one-phase flow, the production in
The well's productivity index (PI or J is common) is: Under pseudo-steady state (pss) , a calculated PI is: The effective permeability-thickness in md-ft ( ) and skin ( s ) are estimated based on well test analyses. productivity index (PI) 1. n. [Well Completions] A mathematical means of expressing the ability of a reservoir to deliver fluids to the wellbore. The PI is usually stated as the volume delivered per psi of drawdown at the sandface (bbl/d/psi). The well is off-center in the y-direction (d y = 1,000 ft; D y = 2,000 ft), centered in the x-direction (d x = D x = 1,000 ft), and off-center in the z-direction (d z = 50 ft; D z = 150 ft). Permeabilities are k x = k y =100 md and k z = 20 md. Wellbore radius is 0.25 ft, B o = 1.25 RB/STB, μ = 1 cp, and s d = 0. Find the productivity index, J. Solution. From Eq.
productivity index (PI) 1. n. [Well Completions] A mathematical means of expressing the ability of a reservoir to deliver fluids to the wellbore. The PI is usually stated as the volume delivered per psi of drawdown at the sandface (bbl/d/psi). The well is off-center in the y-direction (d y = 1,000 ft; D y = 2,000 ft), centered in the x-direction (d x = D x = 1,000 ft), and off-center in the z-direction (d z = 50 ft; D z = 150 ft). Permeabilities are k x = k y =100 md and k z = 20 md. Wellbore radius is 0.25 ft, B o = 1.25 RB/STB, μ = 1 cp, and s d = 0. Find the productivity index, J. Solution. From Eq. The idea, however, did leave the industry with the concept of absolute open flow (AOF). AOF is a common indicator of well productivity and refers to the maximum rate at which a well could flow against a theoretical atmospheric backpressure at the reservoir. The productivity of a gas well is determined with deliverability testing. The constant productivity index concept is only appropriate for oil wells producing under single-phase flow conditions, pressures above the reservoir fluid’s bubblepoint pressure. For reservoir pressures less than the bubblepoint pressure, the reservoir fluid exists as two phases, vapor and liquid, and techniques other than the productivity index must be applied to predict oilwell performance. While these concepts will be dealt with extensively in subsequent chapters, it is useful here to present the productivity index, J, of an oil well (analogous expressions can be written for gas and two-phase wells): First, the dimensioned productivity index with units of flow rate divided by pressure is proportional to the dimensionless (normalized) productivity index J D. The latter, in turn, has very well-known representations. For steady-state flow to a vertical well, The productivity index, PI has been used as a measure of the potential of wells to flow at certain formation pressure drawdown. Additionally, it is used to measure formation damage and formation potential to flow capacity. In ESP-lifted wells, the pressure is boosted by the added number of pump stages.
First, the dimensioned productivity index with units of flow rate divided by pressure is proportional to the dimensionless (normalized) productivity index J D. The latter, in turn, has very well-known representations. For steady-state flow to a vertical well,