Increasing Ultimate Oil Recovery by Infill Drilling and Converting Weak Production Wells to Injection Wells Using Streamline Simulation

2010 ◽  
Author(s):  
Mohammad Sayyafzadeh ◽  
Peyman Pourafshari ◽  
Fariborz Rashidi
Keyword(s):  
Oil Recovery ◽  
Streamline Simulation ◽  
Injection Wells ◽  
Production Wells ◽  
Infill Drilling

Mechanism Analysis of Indigenous Microbial Enhancement for Residue Oil Recovery

2011 ◽  
Vol 365 ◽  
pp. 305-311
Author(s):  
Fu Chang Shu ◽  
Yue Hui She ◽  
Zheng Liang Wang ◽  
Shu Qiong Kong
Keyword(s):  
Oil Recovery ◽  
Mechanism Analysis ◽  
Sweep Efficiency ◽  
Injection Wells ◽  
The North ◽  
Physico Chemical ◽  
Production Wells ◽  
Microbial Enhancement ◽  
Filtration Properties ◽  
Technological Treatment

Biotechnological nutrient flooding was applied to the North block of the Kongdian Oilfield during 2001-2005. The biotechnology involved the injection of a water-air mixture made up of mineral nitrogen and phosphorous salts with the intent of stimulating the growth of indigenous microorganisms. During monitoring of the physico-chemical, microbiological and production characteristics of the North block of the Kongdian bed, it was revealed significant changes took place in the ecosystem as a result of the technological treatment. The microbial oil transformation was accompanied by an accumulation of carbonates, lower fatty acids and biosurfactants in water formations, which is of value to enhanced oil recovery. The microbial metabolites changed the composition of the water formation, favored the diversion of the injected fluid from closed, high permeability zones to upswept zones and improved the sweep efficiency. The results of the studies demonstrated strong hydrodynamic links between the injection wells and production wells. Microbiological monitoring of the deep subsurface ecosystems and the filtration properties of the fluids are well modified, producing 40000 additional tons of oil in the test areas.

A Numerical Simulation Comparison of Five-Spot vs. Line Drive in Micellar/Polymer Flooding

1982 ◽  
Vol 22 (01) ◽  
pp. 69-78
Author(s):  
H. Kazemi ◽  
D.J. MacMillan
Keyword(s):  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Large Scale ◽  
Plug Flow ◽  
Recovery Process ◽  
Field Application ◽  
Polymer Flooding ◽  
Spot Pattern ◽  
Injection Wells ◽  
Production Wells

Abstract The work presented in this paper was undertaken to study the effect of pattern configuration on oil recovery by the Maraflood oil-recovery process. The patterns studied are the five-spot and the 4 × 1 line drive. These patterns are obtained by placing infill wells in an existing 10-acre (40 469-m2) waterflooded five-spot pattern to obtain the 2.5-acre (10 117-m2) patterns. The number of infill wells is the same for both the new five-spot and new line-drive configurations and is about three times the number of existing wells. Both patterns have been used successfully in field applications by Marathon before this study. For instance, a line-drive pattern was used in Project 119-R and a five-spot pattern was used in Project 219-R. This work shows that the line drive produces more tertiary oil than the five-spot under otherwise identical reservoir conditions. Breakthrough times and oil rates for line-drive production wells are nearly the same. Meanwhile, five-spot production wells have vastly differing oil breakthrough times and oil rates. Both of the latter effects result from a nonuniform distribution of waterflood residual oil saturation in the field. Our study also shows that if producing wells in each line-drive row are connected by a perfect vertical fracture and if the same is true of the injection wells, the line-drive efficiency will improve very little. Introduction The Maraflood oil-recovery process is a viable enhanced oil-recovery technique. An appraisal of this process and other surfactant-enhanced oil-recovery schemes was reported by Gogarty. Three significant field tests of the Maraflood process were reported by Earlougher et al. In addition, a large-scale field application of this process was presented recently by Howell et al. in field applications of the Maraflood process, both line-drive and five-spot configurations have been used. In our field experience, an existing five-spot waterflood pattern is convened to another five-spot or 4 × 1 line-drive configuration by adding infill wells. The new five-spot or line-drive pattern has an area-per-well spacing of one-fourth of the original waterflood spacing. In practice, the number of infill wells required for both cases is somewhat greater than three times the number of existing wells. As the total number of wells increases, this ratio approaches the theoretical limit of three. In addition to the preceding arrangements of infill wells, many others are possible. In some arrangements, fewer infill wells are required than in our five-spot and 4 × 1 line drive. In such cases, the area per well increases, which generally causes these problems:required injectivity per injection well increases and may not be attainable because of the high viscosity of the injected fluids andthe breakthrough time is delayed. As an example, consider the case where no infill wells are drilled. In addition to the two problems just listed, the micellar/polymer flooding scheme will sweep only those regions that already have been swept well by the waterflood. The regions left unswept by the waterflood also will be left essentially unswept by the micellar/polymer flood. This means that a substantial amount of oil is left in place. Therefore, these types of undesired patterns were not considered in this study. Patterns with more infill wells than those in this study were not considered because of current economic limitations. Because of the likelihood of economic and technical merits, we also considered the placement of long vertical fractures to connect existing waterflood wells in place of infill wells. The fractures were arranged to form a more effective line drive. We emphasize that the patterns studied in this paper are those usually used in micellar/polymer flooding applications. Muskat has reported breakthrough waterflood sweep efficiencies of 72% and 88% for five-spot and 4 × 1 line drive patterns when the mobility ratio is unity. Muskat's results are for ideal plug flow displacement of red water by blue water in a perfectly homogeneous reservoir. SPEJ P. 69^

The Influence of Geology Factor on Alkaline Surfactant Polymer Flood Effect and the Corresponding Strategy

2016 ◽  
Vol 703 ◽  
pp. 251-255
Author(s):  
Peng Ye ◽  
Dong Zhang ◽  
Lian Bin Zhong ◽  
Guang Wang ◽  
Bin Fu ◽  
...  
Keyword(s):  
Oil Recovery ◽  
Injection Rate ◽  
High Concentration ◽  
Injection Wells ◽  
Adjustment Strategy ◽  
Profile Control ◽  
Production Wells ◽  
Success Experience ◽  
Abandoned Channels ◽  
Alkaline Surfactant Polymer

This study gives the influence laws of abandoned channel, in-layer interlayer, sand body contact relationship on the development effect of the Alkaline Surfactant Polymer (ASP) flooding based on the data of the industry promotion block ( Pu I32、Pu I33 sedimentation), and give out corresponding adjustment strategy at the same time. The result shows that: The ‘abruptly abandoned’ channels have a bad connection with the main channel and possesses a far lower reservoir producing degree (16.1%) than the ‘gradually-abandoned’ channels (79.9%). The injection wells located upon the channel sand need high concentration inject fluid with lower injection rate to handle the polymer breakthrough; The injection wells located between the channels need lower concentration injection; The injection wells located upon the abandoned channels firstly need high concentration injection to achieve the profile control and then inject low concentration fluid to adjust low permeable sublayer; The production wells located upon abandoned channels need timely fracturing measures. By July 2014, water content of this area is 90.7%, oil recovery improved 18.08% and is expected to reach 22.0%. Similar the success experience we get from this area can guide the study of block geologic factors that affect development result and has important guiding significance to the implementation of pointed development adjustment.

scholarly journals THERMAL CYCLE OPTIMIZATION WHEN PROCESSING THE BOTTOM-HOLE ZONE OF WELLS

2020 ◽  
Author(s):  
Sudad H Al-Obaidi ◽  
Guliaeva NI ◽  
Khalaf FH
Keyword(s):  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Heating Zone ◽  
Heavy Oils ◽  
Thermal Impact ◽  
Production Flow ◽  
Injection Wells ◽  
New Methods ◽  
Bottom Hole ◽  
Production Wells

Most of the liquid oil of all types estimated today represents the category of heavy-oils. This leads to decrease in oil production and more extraction of water. Enhanced oil recovery is a method using sophisticated techniques that can deal with such sort of oils and alter the original properties of oil. Thermal Enhanced Oil Recovery (EOR) remains the most frequently used method for extraction of heavy oils. In this work, irreversible changesin rocks that lead to an increase in formation permeability have been studied and, as a result, to an increase in the production flow rate of production wells and for injection wells, an increase in their injectivity. New methods and technologies have been developed for the intensification of thermocyclic well treatments.A computer program based on mathematical model was developed, which allows predicting changes occurring in the well and near the well space. In this model, the main characteristics of the process of cyclic thermal impact on the bottom-hole zone can be used to predict field temperatures in the well and in the formation, as well as changes in the permeability of rocks. To improve the efficiency use of the model and increase the heating zone, a new method of thermal cycling impact on the bottom-hole zone of the well was developed.

scholarly journals CAUSES AND ANALYSIS OF WATER ENCROACHMENT OF SOME OFFSHORE FIELDS PRODUCTS OF AZERBAIJAN

2021 ◽  
Vol 447 (3) ◽  
pp. 112-117
Author(s):  
Novruzova Sudaba ◽  
Gadashova Elmira ◽  
Fariz Ahmed
Keyword(s):  
Fluid Flow ◽  
Oil Recovery ◽  
Oil Production ◽  
Heterogeneous Structure ◽  
New Production ◽  
Injection Wells ◽  
Field Methods ◽  
Stage Of Development ◽  
Production Wells ◽  
The Republic

The results of researches of the water encroachment of some offshore fields (Neft Dashlary, Guneshli, Pirallahi, Darwin Banka, Apsheron Banka, Western Apsheron, etc.) of the Republic of Azerbaijan, most of which are at a late stage of development, have been presented. These fields are represented by weakly cemented and loose reservoirs of heterogeneous structure, in which there is an uneven fluid flow. Water breakthrough occurs through high-permeability layers, and layers with low permeability are involved in development to a less extent. Subsequent attempts to involve them in the development process cause an irrational increase in the volume of injected water, which leads to product encroachment. The type of reservoir, characterized by the presence of fracture zones, contributing to the flow of water from the aquifers to the producing wells, as well as improving their hydrodynamic connection with the injection wells, also contributes to the growth of the rate of watering. The geological and technological reasons for the water encroachment have been determined. The heterogeneity of the above mentioned deposits has been proven. It is indicated that an additional reason for the early water encroachment of production wells is the violation of the annulus tightness. Maintaining high rates of oil production is achieved by bringing in new production wells, while most of the watered wells are retired from operation without having exhausted their potential. It is proposed to carry out the measures that will ensure isolation of the most washed out zones and depleted areas of the main productive layer of the field. Methods of selective water isolation and flow diversion technologies should be carried out, first of all, in wells with an increased density of current reserves in order to obtain additional oil production and increase the oil recovery factor, as well as in wells with a high fluid flow rate.

scholarly journals Economic Analysis of Gas Reinjection for Enhanced Oil Recovery: A Case Study of the Niger Delta

2020 ◽  
pp. 48-64
Author(s):  
Sampson, Ibinye E. ◽  
Akpabio, Julius U. ◽  
Anyadiagwu, Charles I.
Keyword(s):  
Crude Oil ◽  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Niger Delta ◽  
Net Present Value ◽  
Oil And Gas ◽  
Investment Decision ◽  
Petroleum Industry ◽  
Injection Wells ◽  
Production Wells

The instability of crude oil prices at the international market which results in revenue drop to oil and gas operators, the high cost of drilling multiple injection wells and installing gas reinjection systems in a bid to improve recovery of crude oil, have been of great concern to the Petroleum Industry. The Economic viability of Gas Reinjection for Enhanced Oil Recovery (EOR) (as against the gas flaring operation) was analyzed with 7 wells located onshore, in the Niger Delta region of Nigeria. The production history and reservoir data were gathered with which the cost analyses were conducted. Two scenarios involving seven production wells were evaluated. The first was converting two of the production wells to gas injection wells and producing from the remaining 5 production wells (IN2PROD5) and the other was injecting gas in two newly drilled injection wells and producing from the seven production wells (INJ2PROD7). It was shown that (INJ2PROD5) is a preferred option in extending the productive life of an otherwise depleted and uneconomic oilfield, having higher Net Present Value (NPV), Profitability Index (PI) and Internal Rate of Return (IRR) of -$53MM, 0.93 and 27.40% while the INJ2PROD7 had $161MM, 1.39 and 37.75% at discounted rate of 30% respectively. After subjecting the expected net revenues under various crude oil price sensitivity market vagaries, INJ2PROD5 will stand the test of time as it is less expensive and yielded a higher gross profit which is the major factor in any investment decision making.

scholarly journals PEMANTAUAN PROSES INJEKSI AIR PADA LAPANGAN “SMR” CEKUNGAN SUMATERA TENGAH BERDASARKAN DATA ANOMALI TIME-LAPSE MICROGRAVITY

2020 ◽  
Vol 4 (1) ◽  
pp. 112-125
Author(s):  
Dian Pratiwi ◽  
Agung Wiyono
Keyword(s):  
Oil Recovery ◽  
Time Lapse ◽  
Water Dynamics ◽  
Reservoir Rock ◽  
Injection Wells ◽  
Density Reduction ◽  
Injection Process ◽  
A Value ◽  
Production Wells ◽  
The Difference

There had been done a regional research about monitoring of injection process in "SMR" field of Central Sumatera Basin using microgravity method. The time-lapse microgravity method is the development of the gravity method (x, y, z) by adding the fourth dimension of time (t). Monitoring is carried out on production fields that have performed EOR (Enchanced Oil Recovery) ie the process of injecting water into the reservoir to push and drain the remnants of oil in the pores of the reservoir rock to the production well. The microgravity data processing is done by finding the difference between observed gravity values between the first and the second measurements, then performing the spectral analysis to separate the anomaly at reservoir depth and noise. The time-lapse microgravity anomaly has a value of -132.28 μGal to 54.89 μGal. Positive anomalies are related to the injection process, whereas the negative anomalies are related to the production process in the study area. Filtering analysis shows that there are two zones of fluid dynamics, which is due to the process of surface water dynamics (groundwater above reservoir) and that occurs in the reservoir. Fluid reduction zones occur in areas with more production wells than injection wells. Density reduction occurs in the reservoir layer at a depth of 600 m to 1000 m with a maximum reduction value of -3.1x10-3 gr / cm3. The gravity time-lapse inversion model shows the existence of several injection wells that are less effective and therefore need to be stopped injecting.

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.

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