The Enhancement of Horizontal Water Injection Well by Integrating Single Well With Full Field Dynamic Model in Carbonate Reservoir: Case Study from North Kuwait

2020 ◽  
Author(s):  
Luai Ashawesh ◽  
Basel Al-Otaibi ◽  
Vitaly Khoriakov
Keyword(s):  
Dynamic Model ◽  
Water Injection ◽  
Carbonate Reservoir ◽  
Injection Well ◽  
Full Field ◽  
Single Well ◽  
Field Dynamic

Polymer Injection to Unlock Bypassed Oil in a Giant Carbonate Reservoir: Bridging the Gap Between Laboratory and Large Scale Polymer Project

2021 ◽  
Author(s):  
Clement Fabbri ◽  
Haitham Ali Al Saadi ◽  
Ke Wang ◽  
Flavien Maire ◽  
Carolina Romero ◽  
...  
Keyword(s):  
High Salinity ◽  
Water Injection ◽  
Cross Flow ◽  
Carbonate Reservoir ◽  
Carbonate Reservoirs ◽  
Laboratory Work ◽  
High Permeability ◽  
Polymer Injection ◽  
Single Well ◽  
Pilot Design

Abstract Polymer flooding has long been proposed to improve sweep efficiency in heterogeneous reservoirs where polymer enhances cross flow between layers and forces water into the low permeability layers, leading to more homogeneous saturation profile. Although this approach could unlock large volumes of by-passed oil in layered carbonate reservoirs, compatibility of polymer solutions with high salinity - high temperature carbonate reservoirs has been hindering polymer injection projects in such harsh conditions. The aim of this paper is to present the laboratory work, polymer injection field test results and pilot design aimed to unlock target tertiary oil recovery in a highly heterogeneous mixed to oil-wet giant carbonate reservoir. This paper focuses on a highly layered limestone reservoir with various levels of cyclicity in properties. This reservoir may be divided in two main bodies, i.e., an Upper zone and a Lower zone with permeability contrast of up to two orders of magnitude. The main part of the reservoir is currently under peripheral and mid-flank water injection. Field observations show that injected water tends to channel quickly through the Upper zone along the high permeability layers and bypass the oil in the Lower zone. Past studies have indicated that this water override phenomenon is caused by a combination of high permeability contrast and capillary forces which counteract gravity forces. In this setting, adequate polymer injection strategy to enhance cross-flow between these zones is investigated, building on laboratory and polymer injection test field results. A key prerequisite for defining such EOR development scenario is to have representative static and dynamic models that captures the geological heterogeneity of this kind of reservoirs. This is achieved by an improved and integrated reservoir characterization, modelling and water injection history matching procedure. The history matched model was used to investigate different polymer injection schemes and resulted in an optimum pilot design. The injection scheme is defined based on dynamic simulations to maximize value, building on results from single-well polymer injection test, laboratory work and on previous published work, which have demonstrated the potential of polymer flooding for this reservoir. Our study evidences the positive impact of polymer propagation at field scale, improving the water-front stability, which is a function of pressure gradient near producer wells. Sensitivities to the position and number of polymer injectors have been performed to identify the best injection configuration, depending on the existing water injection scheme and the operating constraints. The pilot design proposed builds on laboratory work and field monitoring data gathered during single-well polymer injection field test. Together, these elements represent building blocks to enable tertiary polymer recovery in giant heterogeneous carbonate reservoirs with high temperature - high salinity conditions.

scholarly journals EVOLUTION OF THE COLUMN FOULING PRODUCTION IN WELLS PRODUCING OIL END GAS: CASE STUDY

2014 ◽  
Vol 12 (24) ◽  
pp. 64-70
Author(s):  
Fernando Nunes DA SILVA ◽  
Jardel Dantas DA CUNHA ◽  
Andréa Francisca Fernandes BARBOSA ◽  
Djalma Ribeiro DA SILVA
Keyword(s):  
Formation Mechanism ◽  
Temperature Increase ◽  
Water Injection ◽  
Soxhlet Extraction ◽  
Oil Industry ◽  
Scale Formation ◽  
Injection Well ◽  
Extraction Techniques ◽  
Bicarbonate Ions

In the oil industry the problem of scale formation causes a lot of damage, including the reduction in the production of liquid and thus can be cited oil, also with the increased costs for the production there of. The study of scale is then of paramount importance for the understanding of their formation mechanism and the choice of method for prevention and / or removal. Soxhlet extraction techniques EFRX, XRD and SEM were used to characterize a sample collected in the column of producing a water injection well. Through the analysis of the results was identified scale ferruginous type which its formation is associated with the presence of corrosive agents; and carbonate type, and its formation influenced by the concentration of calcium and bicarbonate ions dissolved in the water , since such formation is common in wells which have a high content of these ions , which is also favored by decreasing the pressure and temperature increase reservoir

Water Injection Enhancement in Tight Carbonate Reservoir through Stim Tunnelling Stimulation Technology. A case study

2015 ◽  
Author(s):  
Jhon Robert Ortiz Requena ◽  
Ahmed Mohamed Fawzy ◽  
Mohamed Abdulla Fahim ◽  
Firdaus Bin Mohamed Noordin ◽  
Noor Nasriq Bin Ujal
Keyword(s):  
Water Injection ◽  
Carbonate Reservoir ◽  
Tight Carbonate

The Use of Tracer Data To Determine Polymer-Flooding Effects in a Heterogeneous Reservoir, 8 Torton Horizon Reservoir, Matzen Field, Austria

2016 ◽  
Vol 19 (04) ◽  
pp. 655-663 ◽  
Author(s):  
Torsten Clemens ◽  
Markus Lüftenegger ◽  
Ajana Laoroongroj ◽  
Rainer Kadnar ◽  
Christoph Puls
Keyword(s):  
Oil Recovery ◽  
Water Injection ◽  
Flow Path ◽  
Injection Well ◽  
Critical Parameters ◽  
Pilot Projects ◽  
Sweep Efficiency ◽  
Full Field ◽  
Polymer Injection ◽  
Production Wells

Summary Polymer-injection pilot projects aim at reducing the uncertainty and risk of full-field polymer-flood implementation. The interpretation of polymer-pilot projects is challenging because of the complexity of the process and fluids moving out of the polymer-pilot area. The interpretation is increasingly more complicated with the heterogeneity of the reservoir. In the polymer pilot performed in the 8 Torton Horizon (TH) reservoir of the Matzen field in Austria, a polymer-injection well surrounded by a number of production wells was selected. A tracer was injected 1 week before polymer injection. The tracer showed that the flow field in the reservoir was dramatically modified with increasing amounts of polymer injected. Despite short breakthrough times of 4 to 10 weeks observed for the tracer, polymer breakthrough occurred only after more than 12 months although injection and production rates were not substantially changed. The tracer signal indicated that the reservoir is heterogeneous, with high flow velocities occurring along a number of flow paths with a limited volume that are strongly connecting the injection and production wells. By injecting polymers, the mobility of the polymer-augmented water was reduced compared with water injection, and led to flow diversion into adjacent layers. The tracer response showed that the speed of the tracer moving from injection to production wells was reduced with increasing amount of polymer injected. This response was used to assess the changes of the amount of water flowing from the injection well to production wells. After a match for the tracer curve was obtained, adsorption, residual resistance factor (RRF), and dispersivity were calculated. The results showed that, even for heterogeneous reservoirs without good conformance of the pilot, the critical parameters for polymer-injection projects can be assessed by analyzing tracer and polymer response. These parameters are required to determine whether implementation of polymer injection at field scale is economically attractive. Along the flow path that is connecting injection and production well, as shown by the tracer response, an incremental recovery of approximately 8% was achieved. The polymer retention and inaccessible pore volume (IPV) in the reservoir were in the same range as in corefloods. Incremental oil recovery caused by acceleration along the flow path was estimated at approximately 20% of the overall incremental oil production caused by polymer injection and 80% was attributed to improved sweep efficiency.

Water Injection Well Performance and Fracture Propagation in a Channel Sand Reservoir: An Offshore Ghana Case Study

2019 ◽  
Author(s):  
Jongsoo Hwang ◽  
Prateek Bhardwaj ◽  
Mukul Sharma ◽  
Sekhar Sathyamoorthy ◽  
Kwarteng Amaning ◽  
...  
Keyword(s):  
Water Injection ◽  
Fracture Propagation ◽  
Injection Well ◽  
Well Performance

Interpretation of Immiscible WAG Repeat Pressure-Falloff Tests

2011 ◽  
Vol 14 (06) ◽  
pp. 687-701 ◽  
Author(s):  
B.A.. A. Stenger ◽  
S.A.. A. Al-Kendi ◽  
A.F.. F. Al-Ameri ◽  
A.B.. B. Al-Katheeri
Keyword(s):  
Water Injection ◽  
Carbonate Reservoir ◽  
Mobility Control ◽  
Reservoir Properties ◽  
Injection Wells ◽  
Pressure Derivative ◽  
Full Field ◽  
Field Development ◽  
Phase Mobility ◽  
Injection Cycle

Summary This paper reviewed the interpretation of repeat pressure-falloff (PFO) tests acquired in two vertical pattern injectors operating in a carbonate reservoir undergoing full-field development. Enhanced vertical-sweep conformance through phase mobility control in the presence of strong reservoir heterogeneity was the major expected benefit from an immiscible water-alternating-gas (WAG) displacement mechanism. PFO tests were carried out during the monophasic injection phase to determine well injectivity and reservoir properties, and were subsequently acquired at the end of each 3-month injection cycle. Analytical falloff-test interpretation relied on the use of the two zone radial composite model. Multiple falloff-test interpretations indicated that the two pattern vertical injectors behaved differently even though both had been fractured. The difference in behavior was linked to different perforated intervals and reservoir properties. Gas- and water-injection rates were showing differences between both pattern injectors as a consequence. Injected gas banks had a small inner radius and were almost undetectable at the end of the subsequent water cycle. Changes in the pressure-derivative slope at the end of the subsequent water-injection cycle indicated most likely the creation of an effective mixing zone of injected gas and water in the reservoir. Numerical finite-volume simulation was required to account for potential injected-fluid segregation and the heterogeneous multilayered nature of the reservoir. Repeat saturation logs acquired in observation wells monitored the saturation distribution away from the injection wells. Fluid saturations derived from the simulation model were showing a good agreement with the analytical results in general, although the need to account for gas trapping was confirmed. Eight planned development WAG injectors were repositioned as a consequence of WAG 1 and WAG 2 pattern performance.

Maximizing Recovery from a Depleted Oil Rim Carbonate Reservoir Through an Integrated FDP Approach: Case Study Onshore Field Abu Dhabi, UAE

2021 ◽  
Author(s):  
Magdy Farouk Fathalla ◽  
Mariam Ahmed Al Hosani ◽  
Ihab Nabil Mohamed ◽  
Ahmed Mohamed Al Bairaq ◽  
Aditya Ojha ◽  
...  
Keyword(s):  
Water Injection ◽  
Primary Objective ◽  
Carbonate Reservoir ◽  
Full Field ◽  
Water Breakthrough ◽  
Artificial Lift ◽  
Reservoir Simulation Model ◽  
Oil Rim ◽  
Project Objectives ◽  
Gas Lift

Abstract This paper examines risk and rewards of co-development of giant reservoir has gas cap concurrently produce with oil rim. The study focus mainly on the subsurface aspects of developing the oil rim with gas cap and impact recoveries on both the oil rim and gas cap. The primary objective of the project was to propose options to develop oil rims and gas cap reservoir aiming to maximize the recovery while ensuring that the gas and condensate production to the network are not jeopardized and the existing facility constraints are accounted. Below are the specific project objectives for each of the reservoirs: To evaluate the heterogeneities of the reservoir using available surveillance information data.To evaluate the reservoir physics and define the depleted oil rims current Gas oil contact and Water Oil Contact using the available surveillance information and plan mitigate reservoir management plan.To propose strategies in co-development plan with increase in oil rim recovery without impact on gas cap recovery.To propose the optimum Artificial methods to extended wells life by minimize the drawn down and reduce bottom head pressure.To propose methods to reduce the well head pressure to reduce back pressure on the wells. The methodology adopted in this study is based on the existing full field compositional reservoir simulation model for proposing different strategical co-development scenario: Auto gas lift Pilot implementation phase.Reactivate using Auto gas lift all the in-active wells.Propose the optimum wells drilling and completion design, like MRC, ERD and using ICV to control water and gas breakthrough.Proposing different field oil production plateauPropose different water injection scheme The study preliminary findings that extended reach drilling (ERD) wells were proposed, The ability to control gas and water breakthrough along the production section will be handled very well by deploying the advanced flow control valves, reactivation of existing Oil rim wells with Artificial lift increases Oil Rim recovery factor, and optimize offtake of gas cap and oil rim is crucial for increase the recovery factories of oil Rim and gas cap.

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