scholarly journals Abnormally high reservoir pressures in areas with a degraded energy state

2021 ◽  
Vol 3 (2) ◽  
pp. 54-60
Author(s):  
R. E. Khadarov ◽  
M. O. Tajibayev
Keyword(s):  
Detailed Analysis ◽  
Energy State ◽  
Reservoir Pressure ◽  
Injection Wells ◽  
Current Energy

Nowadays, in the Uzen and Karamandybas oilfields most of the developed objects show decreasing reservoir pressure. Therefore, there is a need to consider opportunities for increasing the efficiency of the existing system for maintaining reservoir pressure for specific identified areas. This article proposes an approach for a detailed analysis of the current energy state of certain areas through hydrodynamic tests of injection wells in non-stationary filtration modes. The reasons for the occurrence of abnormally high reservoir pressures are presented on the examples of wells, and possible ways to solve them are proposed.

The method for modeling the development of a gas field on the basis of a hierarchy of mathematical models

2019 ◽  
Vol 5 (3) ◽  
pp. 69-82
Author(s):  
Vitaly P. Kosyakov ◽  
Amir A. Gubaidullin ◽  
Dmitry Yu. Legostaev
Keyword(s):  
Mathematical Models ◽  
Energy State ◽  
Reservoir Pressure ◽  
Gas Field ◽  
Water Contact ◽  
Simple Models

This article presents an approach aimed at the sequential application of mathematical models of different complexity (simple to complex) for modeling the development of a gas field. The proposed methodology allows the use of simple models as regularizers for the more complex ones. The main purpose of the applied mathematical models is to describe the energy state of the reservoir — reservoir pressure. In this paper, we propose an algorithm for adapting the model, which allows constructing reservoir pressure maps for the gas field, as well as estimating the dynamics of reservoir pressure with a possible output for determining the position of the gas-water contact level.

scholarly journals Numerical Simulation of the Influence of Geological CO2 Storage on the Hydrodynamic Field of a Reservoir

Geofluids ◽  
2019 ◽  
Vol 2019 ◽  
pp. 1-21
Author(s):  
Zhaoxu Mi ◽  
Fugang Wang ◽  
Zhijie Yang ◽  
Xufeng Li ◽  
Yujie Diao ◽  
...  
Keyword(s):  
Pressure Field ◽  
Co2 Storage ◽  
Shallow Groundwater ◽  
Shallow Aquifer ◽  
Reservoir Pressure ◽  
Geological Storage ◽  
Injection Wells ◽  
Geological Conditions ◽  
Deep Reservoir ◽  
The Impact

CO2 geological storage in deep saline aquifers is an effective way to reduce CO2 emissions. The injection of CO2 inevitably causes a significant pressure increase in reservoirs. When there exist faults which cut through a deep reservoir and shallow aquifer system, there is a risk of the shallow aquifer being impacted by the changes in reservoir hydrodynamic fields. In this paper, a radial model and a 3D model are established by TOUGH2-ECO2N for the reservoir system in the CO2 geological storage demonstration site in the Junggar Basin to analyze the impact of the CO2 injection on the deep reservoir pressure field and the possible influence on the surrounding shallow groundwater sources. According to the results, the influence of CO2 injection on the reservoir pressure field in different periods and different numbers of well is analyzed. The result shows that the number of injection wells has a significant impact on the reservoir pressure field changes. The greater the number of injection wells is, the greater the pressure field changes. However, after the cessation of CO2 injection, the number of injection wells has little impact on the reservoir pressure recovery time. Under the geological conditions of the site and the constant injection pressure, although the CO2 injection has a significant influence on the pressure field in the deep reservoir, the impact on the shallow groundwater source area is minimal and can be neglected and the existing shallow groundwater sources are safe in the given project scenarios.

On the selection of suitable operate durations for injection tests in low permeability reservoirs

2020 ◽  
Vol 6 (1) ◽  
pp. 135-149
Author(s):  
Guzyal F. Asalkhuzina ◽  
Alfred Ya. Davletbaev ◽  
Ildus L. Khabibullin ◽  
Rina R. Akhmetova
Keyword(s):  
Steady State ◽  
Numerical Model ◽  
Low Permeability ◽  
Reservoir Pressure ◽  
Well Test ◽  
Injection Wells ◽  
Fluid Filtration ◽  
Operating Modes ◽  
Low Permeability Reservoirs ◽  
Injection Modes

The article discusses the aspects of conducting and analyzing the results of hydrodynamic studies of wells (well test) at steady-state injection modes conducted in injection wells in order to assess reservoir pressure and injectivity. The main goal of this work is to determine the necessary duration of injection modes at which reservoir pressure will be determined at the maximum research radius. In view of the considerable duration of the study, in low-permeability reservoirs, the work of the environment wells is taken into account, which, in the process of well research, should have a minimal impact on the results of data interpretation. To this end, we simulated the dynamics of pressure changes for this type of well test for various parameters of the reservoir and the duration of injection modes, taking into account the influence of the work of the surrounding production wells. To solve this problem, we used a numerical model of fluid filtration in an element of a nine-point development system in a low-permeable reservoir. The production and injection of fluid is carried out in wells with main technogenic fractures of hydraulic fracturing. During the simulation, the filtration parameters of the “fracture-formation” system and the duration of the well operating modes were varied, and synthetic data on the change in pressure in the wells were reproduced. Pressure and flow rates at the well operating modes were analyzed by plotting the indicator diagram (ID). Estimates of the extrapolated pressure from the ID graphs were compared with the pressures in the numerical model, in particular, the pressure on the supply circuit and on the study radius. It is shown that for low-permeability formations when studying injection wells using the steady-state injection method, it is necessary to take into account the research radius, which depends on the permeability of the formation and the duration of the injection regimes. Also, the research radius must be taken into account when constructing isobar maps along with the reservoir pressure value.

Flood Control Method in Fields with Hard-To-Recover Reserves

2021 ◽  
Author(s):  
Alexander Viktorovich Syundyukov ◽  
Galiaskar Ismagilovich Khabibullin ◽  
Alexander Stanislavovich Trofimchuk ◽  
Denis Radikovich Shaikhatdarov ◽  
Damir Kambirovich Sagitov
Keyword(s):  
Flood Control ◽  
Control Method ◽  
Reservoir Pressure ◽  
Injection Wells ◽  
Hole Pressure ◽  
Oil Displacement ◽  
Maintenance System ◽  
Bottom Hole Pressure ◽  
Bottom Hole ◽  
Half Length

Abstract This paper presents a method for predicting the development of Auto-HF (crack) in injection wells of the reservoir pressure maintenance system during the development of low-permeable reservoirs, in order to ensure the optimal front of oil displacement by water by regulating the bottom-hole pressure of injection wells based on the derived dependence of the half-length of the Auto-HF (crack).

scholarly journals Investigation of the influence of the heterogeneous permeability distribution on the oil phase displacement processes

2021 ◽  
Vol 5 (1(61)) ◽  
pp. 33-40
Author(s):  
Miсhail Lubkov ◽  
Oksana Zakharchuk ◽  
Viktoriia Dmytrenko ◽  
Oleksandr Petrash
Keyword(s):  
Finite Element ◽  
Difference Method ◽  
High Reliability ◽  
Oil Field ◽  
Injection Well ◽  
Shear Direction ◽  
Reservoir Pressure ◽  
Filtration Process ◽  
Injection Wells ◽  
The Impact

The object of research is the filtration processes of displacement of the oil phase under the influence of an injection well in a heterogeneous porous medium. It is possible to evaluate and take into account the effect of reservoir heterogeneity on the distribution of reservoir pressure (and, consequently, on the intensity of the filtration process) using numerical modeling of filtration processes based on the piezoelectric equation. To solve the non-stationary anisotropic problem of piezoconductivity, it is proposed to apply the combined finite-element-difference method of M. Lubkov, which makes it possible to take into account the inhomogeneous distribution of permeability inside the anisotropic oil-bearing formation and at its boundaries, and to adequately calculate the distribution of reservoir pressure. The use of the combined finite-element-difference method allows to combine the advantages of the finite-element method and the finite difference method: to model geometrically complex areas, to find the value at any point of the object under study. At the same time, the use of an implicit difference scheme when finding the nodal values of the grid provides high reliability and convergence of the results. The simulation results show that the distribution of the pressure field between the production and injection wells significantly depends on their location, both in the isotropic landslide and in the anisotropic oil-bearing reservoir. It is shown that the distance between the wells of more than 1 km levels out the effectiveness of the impact of the injection well on the oil filtration process. The influence of the permeability of the oil phase in the shear direction dominates the influence of the permeability in the axial directions (affects the pressure decrease by 4–9.5 %). In the case of a landslide-isotropic reservoir, the wells should be located in the shear (diagonal) direction, which will provide the lowest level of drop in the average reservoir pressure (by 4 %). Based on the information obtained, for the effective use of anisotropic low-permeability formations, it is necessary to place production and injection wells in areas with relatively low anisotropy of the formation permeability, especially to avoid places with the presence of landslide permeability of the formation. The location of the wells is important so that, on the one hand, there is no blockage of oil from the side of reduced permeability, and on the other hand, rapid depletion of the formation from the side of increased permeability does not occur. And also the mutual exchange between the production and injection wells did not stop. When placing a system of production and injection wells in anisotropic formations of an oil field, it is necessary to carry out a systematic analysis of the surrounding anisotropy of the formations in order to place them in such a way that would ensure effective dynamics of filtration processes around these wells. Using the method used, it is possible to predict the impact of an injection well on the distribution of reservoir pressure in the reservoir.

scholarly journals Peramalan Kinerja Lapangan SNP Dengan Injeksi Air Menggunakan Metode Material Balance

2018 ◽  
Vol 1 (3) ◽  
Author(s):  
Andre Albert Sahetapy Engel ◽  
Rachmat Sudibjo ◽  
Muhammad Taufiq Fathaddin
Keyword(s):  
Oil And Gas ◽  
Water Injection ◽  
Material Balance ◽  
Oil And Gas Industry ◽  
Reservoir Pressure ◽  
Injection Wells ◽  
Gas Industry ◽  
Evaluation Result ◽  
Cumulative Production ◽  
The Common

<p>The decline in production from of a field is the common problem in the oil and gas industry. One of the causes of the decrease in production is the decline of reservoir pressure. Based on the analisis result, it was found that SNP field had a weak water drive. The most dominant drive of the field was fluid expansion. In order to reduce the problem, a reservoir pressure maintenance effort was required by injecting water. In this research, the effect of water injection to reservoir pressure and cumulative production was analyzed. From the evaluation result, it was found that the existing inejection performance using one injection well to Zones A and B was not optimum. Because, the recovery factor was predicted to 29.11% only.By activating the four injection wells, the recoverty factor could be increase to 31.43%.</p>

First Successful Controlled Dumpflood in Deepwater Gulf of Mexico Results in Promising Incremental Rate and Recovery

2021 ◽  
Author(s):  
Bilal A. Hakim ◽  
Brandon Thibodeaux ◽  
Chris Brinkman ◽  
Joe Gomes ◽  
Kevin Smith ◽  
...  
Keyword(s):  
Gulf Of Mexico ◽  
Produced Water ◽  
Interdisciplinary Collaboration ◽  
Commodity Prices ◽  
Injection Rate ◽  
Reservoir Modeling ◽  
Reservoir Pressure ◽  
Injection Wells ◽  
Well Completion ◽  
The Cost

Abstract Waterflooding in deepwater reservoirs typically involves injecting seawater or produced water from the surface via pumps into injection wells. This technique is often cost-prohibitive for many reservoirs and poses significant mechanical/operational risks. This paper discusses how one Gulf of Mexico (GOM) operator overcame all these challenges using smart well technology to implement the first controlled dumpflood in deepwater GOM and boosted the injection rate, reservoir pressure, and recovery from a reservoir at a depth of 20,000 ft. In a typical dumpflood project, uncontrolled water production from the aquifer and subsequent injection into the target zone occurs downhole within the same wellbore. Therefore, typical surface and downhole complexities associated with conventional waterflood projects can be avoided. In this first deepwater GOM controlled dumpflood well, the controlled water flow (≥20,000 bbl/d) is directed from the source aquifer to the target oil zone via inflow control valves (ICV). The ICV, downhole permanent pressure gauges, and the downhole flowmeter provide complete surveillance and control of the injection operation to achieve reservoir management and optimize the waterflood objectives. A world-class Pliocene oil reservoir in the deepwater GOM underwent significant pressure depletion due to a weak water-drive mechanism. Extensive subsurface studies and modeling suggested great rock quality and reservoir connectivity, favorable oil-water mobility ratios, and significant upside potential making this reservoir a perfect candidate for waterflooding. Given topsides facility space constraints, a topsides injection was ruled out. Seawater injection via subsea pumping was deemed risky and marginally economical given the high cost and low commodity prices. The asset team then brainstormed ways to minimize the cost and overcome the associated risks and challenges. The asset team envisioned a dumpflood scenario would overcome all the challenges, but a dumpflood had not previously been implemented in the deepwater GOM. From a technical standpoint, all the known risks were identified and addressed, and a low risk factor was determined for this project. After a complex well completion job, the injection rate was ramped-up to ≥20,000 bwpd water via the ICV. An immediate uptick in reservoir pressure and production rate was observed in the producer well 3,000 ft away. Continuous injection has resulted in reservoir pressure and flowrate increases by at least 1,000 psi and 4,000 bopd, respectively, consistent with reservoir modeling estimates. The operator was successful in implementing an existing technology in a unique way in the deepwater environment. A naturally occurring water source at a depth of 19,000 ft was efficiently harvested to increase recovery from a reservoir at a fraction of the cost of a conventional deepwater waterflood project. Great interdisciplinary collaboration and forward thinking enabled the success of this unique project, opening up tremendous possibilities to increase recovery from other fields where a conventional waterflood may not be justifiable.

Current energy state interacts with the developmental environment to influence behavioural plasticity

2019 ◽  
Vol 148 ◽  
pp. 39-51 ◽  
Author(s):  
Raphaël Royauté ◽  
Courtney Garrison ◽  
Jeremy Dalos ◽  
Monica A. Berdal ◽  
Ned A. Dochtermann
Keyword(s):  
Energy State ◽  
Behavioural Plasticity ◽  
Current Energy

scholarly journals IMPROVEMENT OF THE LEVEL OF CONTROL AND MONITORING OF THE RESERVOIR PRESSURE MAINTENANCE SYSTEM THROUGH CREATION OF THE UNIVERSAL MODEL

2016 ◽  
pp. 52-60
Author(s):  
S. I. Grachev ◽  
A. V. Strekalov ◽  
A. T. Khusainov
Keyword(s):  
Theoretical Basis ◽  
Hydraulic System ◽  
Reservoir Pressure ◽  
Comprehensive Model ◽  
Hydraulic Systems ◽  
Unified Approach ◽  
Injection Wells ◽  
Maintenance System ◽  
Pumping Stations ◽  
Software Implementations

The waterflooding process is provided by the technical hydraulic system (THS) of reservoir pressure maintenance, including water intake facilities, treatment systems, pumping stations, pipeline network, shut-off and throttling valves, wellhead equipment of injectors, drained (by boreholes) and flooded (by injection wells) zones of the formation or the system as a whole. The obvious THS interconnection with the productive strata system required a creation of the THS model and the model of productive strata hydraulic system, which should be integrated into a comprehensive model. In the sphere of simulation of hydraulic systems at present there is no theoretical basis formed for building unified hydraulic models related to productive strata systems. Also, there is no unified approach to the mathematical and algorithmic description of models of hydraulic systems with arbitrary properties of elements, due to which the created models and their software implementations are used exclusively in the industry context with large restrictions on description of the properties of the system elements and the boundary conditions.

Sign in / Sign up

Export Citation Format

Share Document