Well bottom-hole flowing pressure evaluation method in 48 Block of S Gas field

Abstract. In the Southern Kanto Gas Field, natural gas dissolved in water has been produced for over 80 years. In order to produce the natural gas dissolved in water, formation water must be pumped from a reservoir in the gas field. The production of formation water is considered to be one of the causes of land subsidence. Because brine injection into shallow formations is expected to be effective to mitigate land subsidence, our association is planning to conduct the pilot test study. In this test, the production and injection of brine are going to be performed, and we will observe a deformation of the shallow formation and a change of ground level and the bottom hole pressure. As a result of these tests, if the land subsidence mitigation effect by injection into shallow formation is confirmed, it is expected that it will be connected to increased production and to reservoir management in consideration of land subsidence mitigation in the future.

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A Calculation Method for Bottom Hole Flowing Pressure Based on Radial Basis Function

Journal of Convergence Information Technology ◽

10.4156/jcit.vol7.issue12.10 ◽

2012 ◽

Vol 7 (12) ◽

pp. 76-84

Author(s):

Jun Ni ◽

Zhanli Ren

Keyword(s):

Radial Basis Function ◽

Basis Function ◽

Calculation Method ◽

Bottom Hole ◽

Radial Basis ◽

Bottom Hole Flowing Pressure

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Role of Gas Viscosity for Shale Gas Percolation

Geofluids ◽

10.1155/2020/8892461 ◽

2020 ◽

Vol 2020 ◽

pp. 1-10

Author(s):

Xiaoming Wang ◽

Junbin Chen ◽

Dazhong Ren ◽

Zhaolong Shi

Keyword(s):

Pressure Drop ◽

Shale Gas ◽

Double Porosity ◽

Gas Viscosity ◽

Important Index ◽

Bottom Hole ◽

Fracture Systems ◽

Bottom Hole Flowing Pressure ◽

Porosity Model

Viscosity is an important index to evaluate gas flowability. In this paper, a double-porosity model considering the effect of pressure on gas viscosity was established to study shale gas percolation through reservoir pressure, gas velocity, and bottom hole flowing pressure. The experimental results show that when pressure affects gas viscosity, shale gas viscosity decreases, which increases the percolation velocity and pressure drop velocity of the free state shale gas in matrix and fracture systems. And it is conducive to the desorption of adsorbed shale gas and effectively supplemented the bottom hole flowing pressure with the pressure wave propagation range and velocity increasing, so that the rate of pressure drop at the bottom of the well slows down, which makes the time that bottom hole flowing pressure reaches stability shortened. Therefore, the gas viscosity should be fully considered when studying the reservoir gas percolation.

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GAS FIELD DELIVERABILITY PREDICTIONS AND DEVELOPMENT ECONOMICS

The APPEA Journal ◽

10.1071/aj66015 ◽

1967 ◽

Vol 7 (1) ◽

pp. 115

Author(s):

A. N. Edgington ◽

N. E. Cleland

Keyword(s):

Material Balance ◽

Production Data ◽

Reservoir Pressure ◽

Computer Programme ◽

Gas Field ◽

Open Flow ◽

Bottom Hole ◽

Present Worth ◽

Net Revenue ◽

Economic Criteria

Forecast of well deliverabilities are an absolute necessity for the realistic planning of the production, transmission and reticulation of natural gas.Gas well deliverability is a function of both natural and artificial limitations and both must be considered in a deliverability forecast.The direct prediction of the decline in wellhead deliverability during the life of a well is a relatively recent development and uses a wellhead relationship analogous to the formation open flow formula. This relationship, combined with the material balance pressure decline equation and the formula relating bottom-hole to wellhead conditions, forms the basis for deliverability forecasts.Compression is added to provide maximum well deliverability and wells may be drilled during the life of a project to maintain deliverability. New wells should meet certain minimum economic criteria before they can be justified. Suggested Criteria are:The net revenue to be earned by the new well must be a pre-selected multiple of the investment required,The present worth of the net revenue discounted at a pre-selected rate must be greater than the investment required.A computer programme has been written to carry out the tedious, repetitive and time-consuming calculations which are necessary for the solution to the problem of deliverability forecasting. This programme calculates the annual production and availability of pipeline gas as well as the number of welJs required to deplete the reserves efficiently. The average reservoir pressure and shut-in and flowing wellhead pressures are forecast and the amount of compression required is calculated. The computer output includes all the production data required for a complete economic analysis of a project involving the depletion of a gas field.

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Adaptive Simulated Annealing Genetic Algorithm for Optimizing Injection Production Parameters of Steam Flood Well

Advanced Materials Research ◽

10.4028/www.scientific.net/amr.328-330.1855 ◽

2011 ◽

Vol 328-330 ◽

pp. 1855-1859

Author(s):

Tian Jian Sun ◽

Jun Feng Shi ◽

Xing He Yu

Keyword(s):

Genetic Algorithm ◽

Simulated Annealing ◽

Steam Temperature ◽

Injection Speed ◽

Simulated Annealing Genetic Algorithm ◽

Bottom Hole ◽

Bottom Hole Flowing Pressure ◽

Steam Flood ◽

Adaptive Simulated Annealing ◽

The Mathematical Model

The development effect of steam flood well is influenced by the combination of the following parameters: injection speed, dryness fraction of steam, temperature of injection steam, and bottom hole flowing pressure. Taking the advantage of adaptive simulated annealing genetic algorithm with the characteristic of fast search and globally optimization, and combine with the mathematical model of the steam flood well. Maximization of the vapor-liquid interface factor is the target to optimize injection production parameter of the steam flood well, the results of the optimization shows that cumulative oil production increases obviously.

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Technology of water shut-off treatment in the gas well using coiled tubing

Oil and Gas Studies ◽

10.31660/0445-0108-2020-6-75-85 ◽

2021 ◽

pp. 75-85

Author(s):

D. S. Leontiev ◽

I. I. Kleshchenko ◽

A. D. Shalyapina ◽

M. M. Mansurova

Keyword(s):

Bottom Water ◽

Urgent Problem ◽

Gas Wells ◽

Flexible Pipe ◽

Gas Field ◽

Gas Well ◽

Coiled Tubing ◽

Bottom Hole ◽

Water Saturated ◽

Gas Fields

In the modern practice of gas field operation, there is a problem associated with the inflow of bottom water to the bottom hole of the well. One of the ways to solve this urgent problem is the introduction of water isolation technologies in the development of gas fields and the use of special compositions and technological equipment for pumping liquids into the watered layers of gas wells. The article deals with the application of a set of special technological measures, such as installation of surface equipment for working in a gas well using coiled tubing, descent of a flexible pipe through a column of pump and compressor pipes with a packer, construction of an inflatable packer, as well as the use of a selective water-insulating composition of the well by pumping it through existing perforation channels in the casing string. Liquids based on ethyl silicate create a kind water shut-off screen between the gas- saturated and water-saturated parts of the gas well formation.

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Prediction Of Shut-in Bottom-hole Pressure From Wellhead Pressure Considering Transient Behaviour Of Hydrostatic Pressure Loss During Shut-in

10.2523/iptc-21241-ms ◽

2021 ◽

Author(s):

Satoshi Maki

Keyword(s):

Hydrostatic Pressure ◽

Pressure Loss ◽

Gas Condensate ◽

Gas Field ◽

Wellhead Pressure ◽

Transient Behaviour ◽

Hole Pressure ◽

Bottom Hole Pressure ◽

Bottom Hole ◽

Surface Data

Abstract Shut-in bottom-hole pressure (SIBHP) is key information to monitor reservoir depletion and thus to evaluate gas in place for a gas field. Permanent downhole gauges are widely used to continuously measure bottom-hole pressure especially for subsea wells. However, when gauges fail, a large cost of workover for gauge replacement is a major problem. In case of the gauge failure, SIBHP hence needs to be estimated from measured surface data such as wellhead pressure (WHP) and wellhead temperature (WHT). The use of WHT for subsea wells however leads to a large error of the SIBHP calculation because sea current significantly affects WHT readings during shut-in. This study aims to develop a correlation methodology to predict SIBHP from surface data without using WHT. We have developed a linear correlation of hydrostatic pressure loss during shut-in with superposition time to predict SIBHP from WHP. Using superposition time of well production status with zero or one indicator effectively accounts for transient behaviour of hydrostatic pressure loss caused by cooling of wellbore fluid and pressure build-up. The transient behaviour differs by individual wells. Hence, the coefficients of the correlation were calibrated well by well to reproduce observed SIBHP. The correlations were applied to the Ichthys gas-condensate field located in the Browse Basin, North West Shelf of Australia. SIBHP trends are reasonably reproduced by the correlations after calibration. A blind test was performed using additional 18 months production data to investigate the predictability of the proposed correlation. As a result, high accuracy of the prediction is confirmed with an average absolute error of approximately 0.4% for the test period. The SIBHP of wells in which downhole gauges have failed is predicted by the calibrated correlations, and the predicted SIBHP is utilised for the reservoir management of the Ichthys field. We present the novel methodology to predict SIBHP from observed surface data without WHT for subsea gas-condensate wells considering the transient behaviour of hydrostatic pressure loss. The proposed correlation provides accurate prediction of SIBHP in case of the gauge failure.

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