Influence of Adjacent Conductive Formations on the Selective Electric Reservoir Heating Process

1982 ◽  
Vol 22 (05) ◽  
pp. 750-754 ◽  
Author(s):  
A. Herbert Harvey
Keyword(s):  
Electric Current ◽  
Oil Recovery ◽  
Voltage Drop ◽  
Outer Boundary ◽  
Heating Process ◽  
Temperature Sensitive ◽  
Oil Reservoir ◽  
Injection Wells ◽  
Heated Oil ◽  
Alternating Electric Current

Abstract A mathematical model is proposed for approximating the distribution of resistance heating in a process that employs an alternating electric current to heat an oil reservoir. The model assumes radial flow both of fluid and of current. Introduction We have been investigating the feasibility of an oil recovery technique that would employ an alternating electric current to heat an oil reservoir. The process should improve the mobility ratio at the displacement front, since the viscosity of most oils is more temperature-sensitive than the viscosity of water. Thermal expansion of heated oil also may make some contribution to oil recovery. The selective electric reservoir heating (SERH) process would employ electrodes installed in water injection wells, and high-salinity water would be injected during heating. This low-resistivity fluid would reduce heating in the portion of the reservoir that has been invaded by this fluid. It also would cool the electrode sufficiently so that boiling (which would break the electric circuit) would not occur, and it would displace some of the heated oil to production wells where it can be recovered. Model for Resistive Adjacent Beds A relatively simple model of the heating process can be developed if we consider a homogeneous, horizontal, isotropic reservoir that is uniform in thickness and bounded above and below by highly resistive formations. For this system we assume that the flows both of injected water and of electricity are radial near the injection well (Fig. 1). The region invaded by injected water is a cylinder with radius r and an average resistivity of R. The outer boundary of the model used to represent the system is a cylinder with a radius of r, which is half the distance between adjacent electrode wells in a pattern flood. The average resistivity of the portion of the reservoir that has not yet been contacted by injected water is R. Since we have assumed that R and R are not functions of r, and since the same current flows in the invaded and uninvaded zones, we can show by integration of Ohm's law that percent heating (1) percent heating (1) where Eq. 1 gives the percentage of heating that occurs in the uninvaded portion of the reservoir (where heating is desired) when the radius of the invaded portion of the reservoir is r. The percentage of heating that occurs in the uninvaded zone is equal to the percentage of the voltage drop that occurs in this zone. Resistivities in Eq. 1 may be estimated. (2) (3) These resistivities are functions of time, since water resistivity decreases with an increase in temperature, and since water saturations may change during the recovery process. process. If we consider the case of a constant injection rate, with injected water displacing the formation water, the radius of the invaded zone is given by (4) SPEJ P. 750

Slowing Production Decline and Extending the Economic Life of an Oil Field: New MEOR Technology

2002 ◽  
Vol 5 (01) ◽  
pp. 33-41 ◽  
Author(s):  
L.R. Brown ◽  
A.A. Vadie ◽  
J.O. Stephens
Keyword(s):  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Enhanced Recovery ◽  
Water Injection ◽  
Oil Production ◽  
Oil Field ◽  
Economic Life ◽  
Oil Reservoir ◽  
Injection Wells ◽  
Black Warrior Basin

Summary This project demonstrated the effectiveness of a microbial permeability profile modification (MPPM) technology for enhancing oil recovery by adding nitrogenous and phosphorus-containing nutrients to the injection water of a conventional waterflooding operation. The MPPM technology extended the economic life of the field by 60 to 137 months, with an expected recovery of 63 600 to 95 400 m3 (400,000 to 600,000 bbl) of additional oil. Chemical changes in the composition of the produced fluids proved the presence of oil from unswept areas of the reservoir. Proof of microbial involvement was shown by increased numbers of microbes in cores of wells drilled within the field 22 months after nutrient injection began. Introduction The target for enhanced oil recovery processes is the tremendous quantity of unrecoverable oil in known deposits. Roughly two thirds [approximately 55.6×109 m3 (350 billion bbl)] of all of the oil discovered in the U.S. is economically unrecoverable with current technology. Because the microbial enhanced oil recovery (MEOR) technology in this report differs in several ways from other MEOR technologies, it is important that these differences be delineated clearly. In the first place, the present project is designed to enhance oil recovery from an entire oil reservoir, rather than treat single wells. Even more important is the fact that this technology relies on the action of the in-situ microflora, not microorganisms injected into the reservoir. It is important to note that MPPM technology does not interfere with the normal waterflood operation and is environmentally friendly in that neither microorganisms nor hazardous chemicals are introduced into the environment. Description of the Oil Reservoir. The North Blowhorn Creek Oil Unit (NBCU) is located in Lamar County, Alabama, approximately 75 miles west of Birmingham. This field is in what is known geologically as the Black Warrior basin. The producing formation is the Carter sandstone of Mississippian Age at a depth of approximately 700 m (2,300 ft). The Carter reservoir is a northwest/ southeast trending deltaic sand body, approximately 5 km (3 miles) long and 1 to 1.7 km (1/2 to 1 mile) wide. Sand thickness varies from only 1 m up to approximately 12 m (40 ft). The sand is relatively clean (greater than 90% quartz), with no swelling clays. The field was discovered in 1979 and initially developed on 80-acre spacing. Waterflooding of the reservoir began in 1983. The initial oil in place in the reservoir was approximately 2.54×106 m3 (16 million bbl), of which 874 430 m3 (5.5 million bbl) had been recovered by the end of 1995. To date, North Blowhorn Creek is the largest oil field discovered in the Black Warrior basin. Oil production peaked at almost 475 m3/d (3,000 BOPD) in 1985 and has since declined steadily. Currently, there are 20 injection wells and 32 producing wells. Oil production at the outset of the field demonstration was approximately 46 m3/d oil (290 BOPD), 1700 m3/d gas (60 MCFD), and 493 m3/d water (3,100 BWPD), with a water-injection rate of approximately 660 m3/d (4,150 BWPD). Projections at the beginning of the project were that approximately 1.59×106 m3 oil (10 million bbl of oil) would be left unrecovered if some new method of enhanced recovery were not effective. Prefield Trial Studies The concepts of the technology described in this paper had been proven to be effective in laboratory coreflood experiments.1,2 However, it seemed advisable to conduct coreflood experiments with cores from the reservoir being used in the field demonstration. Toward this end, two wells were drilled, and cores were obtained from one for the laboratory coreflood experiments to determine the schedule and amounts of nutrients to be employed in the field trial.3

Screening Criteria for Dump-flood Projects Implementation in Indonesia Fields

2021 ◽  
Author(s):  
A. K. Widi
Keyword(s):  
Oil Recovery ◽  
Water Injection ◽  
Critical Parameters ◽  
Oil Reservoir ◽  
Oil Viscosity ◽  
Injection Wells ◽  
Screening Criteria ◽  
Field Problem ◽  
The Status ◽  
Porosity And Permeability

Dump-flooding is a process of water flowing from higher-pressure-aquifer/ -water-bearing-reservoir to lower and depleted-pressure-oil reservoir through casing of the same well. This method is introduced to resolve groundwater scarcity of remote field problem. Furthermore, dump flood is a more cost-friendly method compare with conventional water injection, as it does not require water surface facility, more injection wells, and injection pipelines. Although dump-flooding has been successfully applied in many oilfields in the world, yet there is no standardized screening criteria that have been published. Therefore, this paper intends to generate a dump flood-organized-screening table to acquire potential oil reservoir candidates in Indonesia through dumpflooding projects based on the screening results. The screening table was constructed by gathering reservoir, aquifer, and fluid property data from positively-applied-dump flood project-oilfield. Two sensitivity methods – radar plot and CORRELL – were used to define critical and non-critical parameters which affected the oil recovery factor value. After being analyzed, the sensitivity results from CORRELL method were selected considering it is used frequently to measure the strength of the relationship between two variables. There are seven critical parameters (oil viscosity, reservoir permeability and porosity, depth, reservoir temperature, and aquifer porosity and permeability) that influence the decision to perform dump-flooding in one field. There are 134 out of 264 oilfields in Indonesia were tested with confident of 90% that were screened afterward. In addition, there are two factors to determine “go/no-go” decision, those are: range of tolerance and uncertainty. The status of the project can be declared as “go” if there is no out-of-tolerance-range-parameter and the uncertainty accumulation parameters is below 30%. After screening, 75 out of 134 fields were passed, where the majority of them were sandstone reservoirs with a dominant light oil compositions and been previously water flooded

scholarly journals Enhanced oil recovery mechanisms of polymer flooding in a heterogeneous oil reservoir

2021 ◽  
Vol 48 (1) ◽  
pp. 169-178
Author(s):  
Xiangguo LU ◽  
Bao CAO ◽  
Kun XIE ◽  
Weijia CAO ◽  
Yigang LIU ◽  
...  
Keyword(s):  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Polymer Flooding ◽  
Oil Reservoir ◽  
Recovery Mechanisms

scholarly journals Mesenchymal Stem Cell Osteodifferentiation in Response to Alternating Electric Current

2013 ◽  
Vol 19 (3-4) ◽  
pp. 467-474 ◽  
Author(s):  
Courtney M. Creecy ◽  
Christine F. O'Neill ◽  
Bernard P. Arulanandam ◽  
Victor L. Sylvia ◽  
Christopher S. Navara ◽  
...  
Keyword(s):  
Stem Cell ◽  
Mesenchymal Stem Cell ◽  
Electric Current ◽  
Alternating Electric Current

The New Generation of Outflow Control Devices Autonomously Controlling the Conformance of Water Injection Well- A Case Study with ADNOC Onshore

2021 ◽  
Author(s):  
Sultan Ibrahim Al Shemaili ◽  
Ahmed Mohamed Fawzy ◽  
Elamari Assreti ◽  
Mohamed El Maghraby ◽  
Mojtaba Moradi ◽  
...  
Keyword(s):  
Oil Recovery ◽  
Dynamic Properties ◽  
Short Circuit ◽  
Water Injection ◽  
Performance Outcomes ◽  
Injection Well ◽  
Well Performance ◽  
Injection Wells ◽  
Horizontal Section ◽  
Control Devices

Abstract Several techniques have been applied to improve the water conformance of injection wells to eventually improve field oil recovery. Standalone Passive flow control devices or these devices combined with Sliding sleeves have been successful to improve the conformance in the wells, however, they may fail to provide the required performance in the reservoirs with complex/dynamic properties including propagating/dilating fractures or faults and may also require intervention. This is mainly because the continuously increasing contrast in the injectivity of a section with the feature compared to the rest of the well causes diverting a great portion of the injected fluid into the thief zone which ultimately creates short-circuit to the nearby producer wells. The new autonomous injection device overcomes this issue by selectively choking the injection of fluid into the growing fractures crossing the well. Once a predefined upper flowrate limit is reached at the zone, the valves autonomously close. Well A has been injecting water into reservoir B for several years. It has been recognised from the surveys that the well passes through two major faults and the other two features/fractures with huge uncertainty around their properties. The use of the autonomous valve was considered the best solution to control the water conformance in this well. The device initially operates as a normal passive outflow control valve, and if the injected flowrate flowing through the valve exceeds a designed limit, the device will automatically shut off. This provides the advantage of controlling the faults and fractures in case they were highly conductive as compared to other sections of the well and also once these zones are closed, the device enables the fluid to be distributed to other sections of the well, thereby improving the overall injection conformance. A comprehensive study was performed to change the existing dual completion to a single completion and determine the optimum completion design for delivering the targeted rate for the well while taking into account the huge uncertainty around the faults and features properties. The retrofitted completion including 9 joints with Autonomous valves and 5 joints with Bypass ICD valves were installed in the horizontal section of the well in six compartments separated with five swell packers. The completion was installed in mid-2020 and the well has been on the injection since September 2020. The well performance outcomes show that new completion has successfully delivered the target rate. Also, the data from a PLT survey performed in Feb 2021 shows that the valves have successfully minimised the outflow toward the faults and fractures. This allows achieving the optimised well performance autonomously as the impacts of thief zones on the injected fluid conformance is mitigated and a balanced-prescribed injection distribution is maintained. This paper presents the results from one of the early installations of the valves in a water injection well in the Middle East for ADNOC onshore. The paper discusses the applied completion design workflow as well as some field performance and PLT data.

The measuring system for monitoring the microarc heating process during surface hardening of steel products

2021 ◽  
pp. 33-39
Author(s):  
Makar S. Stepanov ◽  
rina G. Koshlyakova
Keyword(s):  
Heat Treatment ◽  
Mathematical Model ◽  
Electric Current ◽  
Measurement Method ◽  
Sample Surface ◽  
Steel Sample ◽  
Measuring System ◽  
Heating Process ◽  
Carbon Powder ◽  
Measured Temperature

The accelerated heat treatment during steel products hardening technology has been investigated. The possibility of measuring the temperature of steel products by thermoelectric platinum-platinum-rhodium thermocouple under microarc heating conditions is analyzed. During the experiments, working junctions of two S-type thermocouples: working and standard, were coined into the sample surface at the same level. The free thermocouples ends were connected to a digital multimeter and a personal computer. It was determined that 5 factors affect the measurement results: the electric current strength in the circuit, carbon powder, calibration, number of repeated measurement cycles, and a thermocouple copy. When planning the experiment, the concept of conducting a step-by-step nested experiment was used. Variance analysis method was used to process the experimental results. The measurement method precision parameters were calculated: repeatability and reproducibility. A linear mathematical model linking the measurement method reproducibility index with the measured temperature value has been obtained. A linear mathematical model is obtained that relates the reproducibility index of the measurement method to the measured temperature value. A measuring system for the experimental determination of the temperature of a steel sample is proposed and its application is justified for different electric current densities on the sample surface and varying duration of microarc heating. The possibilities of selecting and controlling the microarc heating modes depending on the required temperature of the heat treatment of the steel product are determined.

Enhancing oil recovery by electric current impulses well treatment: A case of marginal field from Oman

Fuel ◽  
2022 ◽  
Vol 314 ◽  
pp. 123115
Author(s):  
Svetlana Rudyk ◽  
Usman Taura ◽  
Mohammed Al-Jahwary
Keyword(s):  
Electric Current ◽  
Oil Recovery ◽  
Marginal Field

Shear-layers in magnetohydrodynamic spherical Couette flow with conducting walls

2010 ◽  
Vol 645 ◽  
pp. 145-185 ◽  
Author(s):  
A. M. SOWARD ◽  
E. DORMY
Keyword(s):  
Magnetic Field ◽  
Shear Layer ◽  
Electric Current ◽  
Current Flow ◽  
Outer Boundary ◽  
Free Shear Layer ◽  
Viscous Effects ◽  
Current Leakage ◽  
Axisymmetric Motion ◽  
Relative Conductance

We consider the steady axisymmetric motion of an electrically conducting fluid contained within a spherical shell and permeated by a centred axial dipole magnetic field, which is strong as measured by the Hartmann number M. Slow axisymmetric motion is driven by rotating the inner boundary relative to the stationary outer boundary. For M ≫ 1, viscous effects are only important in Hartmann boundary layers adjacent to the inner and outer boundaries and a free shear-layer on the magnetic field line that is tangent to the outer boundary on the equatorial plane of symmetry. We measure the ability to leak electric current into the solid boundaries by the size of their relative conductance ɛ. Since the Hartmann layers are sustained by the electric current flow along them, the current inflow from the fluid mainstream needed to feed them increases in concert with the relative conductance, because of the increasing fraction ℒ of the current inflow leaked directly into the solids. Therefore the nature of the flow is sensitive to the relative sizes of ɛ−1 and M.The current work extends an earlier study of the case of a conducting inner boundary and an insulating outer boundary with conductance ɛo = 0 (Dormy, Jault & Soward, J. Fluid Mech., vol. 452, 2002, pp. 263–291) to other values of the outer boundary conductance. Firstly, analytic results are presented for the case of perfectly conducting inner and outer boundaries, which predict super-rotation rates Ωmax of order M1/2 in the free shear-layer. Successful comparisons are made with numerical results for both perfectly and finitely conducting boundaries. Secondly, in the case of a finitely conducting outer boundary our analytic results show that Ωmax is O(M1/2) for ɛo−1 ≪ 1 ≪ M3/4, O(ɛo2/3M1/2) for 1 ≪ ɛo−1 ≪ M3/4 and O(1) for 1 ≪ M3/4 ≪ ɛo−1. On increasing ɛo−1 from zero, substantial electric current leakage into the outer boundary, ℒo ≈ 1, occurs for ɛo−1 ≪ M3/4 with the shear-layer possessing the character appropriate to a perfectly conducting outer boundary. When ɛo−1 = O(M3/4) the current leakage is blocked near the equator, and the nature of the shear-layer changes. So, when M3/4 ≪ ɛo−1, the shear-layer has the character appropriate to an insulating outer boundary. More precisely, over the range M3/4 ≪ ɛo−1 ≪ M the blockage spreads outwards, reaching the pole when ɛo−1 = O(M). For M ≪ ɛo−1 current flow into the outer boundary is completely blocked, ℒo ≪ 1.

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