Reservoir management of the mature Windalia waterflood field by optimising water injection allocation

2012 ◽  
Vol 52 (2) ◽  
pp. 705
Author(s):  
Andrew Haynes ◽  
Lina Hartanto ◽  
Wee Yong Gan ◽  
Morteza Sayarpour
Keyword(s):  
Water Availability ◽  
Water Injection ◽  
Reservoir Management ◽  
Dynamic Allocation ◽  
Water Handling ◽  
Production Wells ◽  
Injection Water ◽  
Water Volumes ◽  
Geometric Layout ◽  
Management Capabilities

Barrow Island’s Windalia reservoir is Australia’s largest onshore waterflooding operation, developed in 1965 with waterflooding starting in 1967. The Windalia reservoir is highly heterogeneous and geologically complex, showing low permeabilities and extensive fault networks. Presently, injection rates are constrained by water availability because of aging source water facilities and increased injector failures because of high integrity risks, highlighting the importance of optimised distribution of injection volumes. Static allocation of injection water has historically been conducted on a pattern basis. This approach, however, is not grounded on the relationships between injection and production wells; instead, it honours the geometric layout of the wells. A more dynamic approach was required to account for the changes in status of injectors and water availability that are often encountered in mature waterflood systems. The successful completion of the Windalia capacitance-resistance model (CRM) was leveraged to develop a comprehensive ranking system of all capable injectors, quantifying short-term normalised oil response to maximise the oil production achieved for a given volume of water injected. Improved understanding of injector-producer communication has also provided the ability to extract the maximum value from limited injection water volumes and has the potential to reduce water cycling and the associated water-handling costs. It can also improve the ability to identify and prioritise workover and stimulation opportunities. This work describes the advances in reservoir management capabilities by quantifying the relationships between injector-producer pairs and the dynamic allocation of injection volumes.

Value of DTS in Multi-Stacked Reservoirs to Better Understand Injectivity and Water Flood Effectiveness – A Field Example from the UAE

2021 ◽  
Author(s):  
Jorge Gomes ◽  
Jane Mason ◽  
Graham Edmonstone
Keyword(s):  
Lower Cretaceous ◽  
Fiber Optic ◽  
Water Movement ◽  
Water Injection ◽  
Reservoir Management ◽  
Oil Production ◽  
Temperature Sensing ◽  
Dense Layer ◽  
Distributed Temperature Sensing ◽  
Injection Water

This paper highlights the application of downhole fiber optic (FO) distributed temperature sensing (DTS) measurements for well and reservoir management applications: 1) Wellbore water injectivity profiling. 2) Mapping of injection water movement in an underlying reservoir. The U.A.E. field in question is an elongated anticline containing several stacked carbonate oil bearing reservoirs (Figure 1). Reservoir A, where two DTS monitored, peripheral horizontal water injectors (Y-1 and Y-2) were drilled, is less developed and tighter than the immediately underlying, more prolific Reservoir B with 40 years of oil production and water injection history. Reservoirs A and B are of Lower Cretaceous age, limestone fabrics made up of several 4th order cycles, subdivided by several thin intra dense, 2-5 ft thick stylolitic intervals within the reservoir zones. Between Reservoir A and Reservoir B there is a dense limestone interval (30-50 ft), referred as dense layer in the Figure 1 well sections.

An Enhanced Cost-Effective Approach for WI Optimization Implemented in a Giant Carbonate Reservoir Undergoing a Transition Scheme from Peripheral to Pattern Injection

2021 ◽  
Author(s):  
Maryvi Martinez ◽  
Jhon Ortiz ◽  
Fatmah Alshehhi ◽  
Bhanu Bethapudi ◽  
Krisna Permana ◽  
...  
Keyword(s):  
Task Force ◽  
Water Injection ◽  
Material Balance ◽  
Reservoir Management ◽  
Carbonate Reservoir ◽  
Maintenance Cost ◽  
Water Handling ◽  
Short Period ◽  
The Impact ◽  
Successful Integration

Abstract With the aim to fulfil a more comprehensive and effective water injection optimization strategy in a giant carbonate reservoir, the asset carried out a dedicated study for a giant carbonate unit (Unit-M) to evaluate the specific challenges and define mitigation actions to improve the reservoir performance. This paper outlines the experience of the successful integration and strong collaborative environment between Reservoir Management Surveillance-Studies, Water Handling, Optimization and Production Operations teams through the project execution leading to optimal solutions in a short period, in accordance with a long-term plan oriented to effectively manage future injection requirements. These actions allowed a favorable impact on the operating costs associated to the new and more efficient water balancing. Water injection, oil production, and reservoir pressure performance in addition to surveillance data for Unit-M have been analyzed at region and well scale. A better-detailed understanding about Peripheral and pattern injection Balance using streamline simulation and material balance analysis provided the support to implement actions that include: reactivation of the pilot pattern WI wells, redistribution of Water Injection in the periphery, maximize the efficiency of the Water injectors (Roll Up, re-utilization in other units, P&A) and Optimize clusters utilization. Moreover, the reservoir simulation was used to verify the impact of the new Water Injection strategy in pressure maintenance, sweep efficiency and the ultimate recovery expected. The conformation of a dedicated task force team between Water Handling Operations and Development teams enable the alignment to common goals and a successful integration that led to define short term actions and mitigate present challenges of waterflood reservoir management. Effective and timely application of these solutions resulted in significant reduced maintenance cost (+/-30%) of the wells and clusters involved.

scholarly journals Capacity Requirements Planning in Water Injection Plant (WIP) Facilities of the Exploration Wells at Oil Company

2019 ◽  
Vol 1 (1) ◽  
pp. 36-46
Author(s):  
Meilita Tryana Sembiring ◽  
Sri Ivan Madriansyah ◽  
Muhammad Haikal Sitepu
Keyword(s):  
Production Process ◽  
Capacity Planning ◽  
Economic Value ◽  
Water Injection ◽  
Reservoir Pressure ◽  
Petroleum Production ◽  
Injection Pump ◽  
Artificial Lift ◽  
Production Wells ◽  
Injection Water

In production wells, in line with the production time there is a decrease in reservoir pressure and this condition causes a reduction in the economic value of the well. The problem of wells that have decreased production capability caused by a decrease in reservoir pressure can be overcome by means of artificial lift methods. Water injection is a method of injecting by re-injecting water that is carried along with oil during the petroleum production process using an injection pump. Based on this, capacity planning is needed in relation to the need for injection pump engines in the operating area so that the petroleum production process can run smoothly. The method used is to perform formation water forecasting needed in each exploration wells based on historical data injection water formation to obtain a plan regarding the capacity of the pump engine to be used in the coming period. Based on the results of forecasting, it is known that 32 periods have the possibility to exceed WIP capacity by 2000 bwpd. From the observations, an additional 2000 bwpd is needed to increase WTP capacity to 4000 bwpd with the proposed cost needed for the procurement of injection water per month is Rp. 22.083.333 compared to the previous required cost of Rp. 32.129.400,- per month.

Subsea Water Injection-Water Quality Management

2005 ◽  
Author(s):  
J. Michaelsen ◽  
B. Bergu ◽  
J. Marrelli ◽  
M. Theobald
Keyword(s):  
Water Quality ◽  
Quality Management ◽  
Water Quality Management ◽  
Water Injection ◽  
Injection Water

Development of efficiency increase methods for water injection

2020 ◽  
pp. 57-60
Author(s):  
K.I. Mustafaev ◽  
◽  
◽  
Keyword(s):  
Water Injection ◽  
Cost Effective ◽  
Current Interest ◽  
Residual Oil ◽  
Production Well ◽  
Field Development ◽  
Oil Reserves ◽  
Production Wells ◽  
Efficiency Increase

The production of residual oil reserves in the fields being in a long-term exploitation is of current interest. The extraction of residual oil in such fields was cost-effective and simple technological process and is always hot topic for researchers. Oil wells become flooded in the course of time. The appearance of water shows in production wells in the field development and operation is basically negative occurrence and requires severe control. Namely for this reason, the studies were oriented, foremost, to the prevention of water shows in production well and the elimination of its complications as well. The paper discusses the ways of reflux efficiency increase during long-term exploitation and at the final stages of development to prevent the irrigation and water use in production wells.

scholarly journals Studying of changes in the interaction of well during the water injection process

2019 ◽  
pp. 81-85
Author(s):  
Damir K. Sagitov
Keyword(s):  
Correlation Coefficient ◽  
Pair Correlation ◽  
Water Injection ◽  
Reservoir Pressure ◽  
Maintenance System ◽  
Displacement Front ◽  
Injection Process ◽  
Production Wells

The study of the causes of changes in the effectiveness of the reservoir pressure maintenance system in terms of the interaction of injection and production wells is an important and insufficiently studied problem, especially in terms of the causes of the attenuation of stable connections between the interacting wells. Based on the results of the calculation of the Spearman pair correlation coefficient, the reasons for the change in the interaction of wells during the flooding process at various stages were estimated. Of particular interest are identified four characteristic interactions, which are determined by the periods of formation of the displacement front.

scholarly journals Polymer gels for controlling water thief zones in injection wells

2012 ◽  
Vol 5 (1) ◽  
pp. 37-44 ◽  
Author(s):  
Gustavo-Adolfo Maya-Toro ◽  
Rubén-Hernán Castro-García ◽  
Zarith del Pilar Pachón-Contreras. ◽  
Jose-Francisco Zapata-Arango
Keyword(s):  
Oil Recovery ◽  
Water Injection ◽  
Injection Wells ◽  
Recovery Processes ◽  
Injection Water ◽  
Secondary Oil Recovery ◽  
High Concentrations ◽  
Low Efficiency ◽  
Hydrolyzed Polyacrylamide ◽  
Positive Results

Oil recovery by water injection is the most extended technology in the world for additional recovery, however, formation heterogeneity can turn it into highly inefficient and expensive by channeling injected water. This work presents a chemical option that allows controlling the channeling of important amounts of injection water in specific layers, or portions of layers, which is the main explanation for low efficiency in many secondary oil recovery processes. The core of the stages presented here is using partially hydrolyzed polyacrylamide (HPAM) cross linked with a metallic ion (Cr+3), which, at high concentrations in the injection water (5000 – 20000 ppm), generates a rigid gel in the reservoir that forces the injected water to enter into the formation through upswept zones. The use of the stages presented here is a process that involves from experimental evaluation for the specific reservoir to the field monitoring, and going through a strict control during the well intervention, being this last step an innovation for this kind of treatments. This paper presents field cases that show positive results, besides the details of design, application and monitoring.

Solubility Of Common Oil Field Scales Of Injection Water And High–barium Concentration And High–salinity Formation Water

2012 ◽  
Author(s):  
Amer Badr Merdhah ◽  
Abu Azam Mohd Yassin
Keyword(s):  
Oil And Gas ◽  
High Salinity ◽  
Sea Water ◽  
Water Injection ◽  
Gas Production ◽  
Oil Field ◽  
Formation Water ◽  
Oil And Gas Production ◽  
Barium Concentration ◽  
Injection Water

Kerak pemendapan merupakan satu daripada masalah paling penting dan serius dalam sistem suntikan air. Kerak kadangkala mengehadkan atau menghalang penghasilan gas dan minyak melalui penyumbatan matrik atau perpecahan pembentukan minyak dan jeda yang berlubang. Makalah ini mengetengahkan kesimpulan pengukuran makmal bagi kerak terbentuk di dalam keterlarutan medan minyak biasa dalam sintetik air masin (pembentukan air dan air laut) bagi pembentukan air yang mengandungi barium dan kandungan garam yang tinggi pada suhu 40 hingga 90°C pada tekanan atmosfera. Keputusan uji kaji mengesahkan pola kebergantungan keterlarutan bagi kerak medan minyak biasa pada keadaan ini. Pada suhu yang lebih tinggi, kerak bagi CaCO3, CaSO4, dan SrSO4 meningkat manakala kerak BaSO4 menurun disebabkan oleh keterlarutan CaCO3, CaSO4, dan SrSO4 menurun dan keterlarutan BaSO4 meningkat dengan kenaikan suhu. Kata kunci: Masalah pengskalaan; skala keterlarutan; paras kandungan garam tinggi; logam barium tinggi Scale deposition is one of the most important and serious problems which water injection systems are generally engaged in. Scale sometimes limits or blocks oil and gas production by plugging the oil–producing formation matrix or fractures and the perforated intervals. This paper presents a summary of the laboratory measurements of the solubility of common oil field scales in synthetic brines (formation water and sea water) of high–barium and high–salinity formation waters at 40 to 90°C and atmospheric pressure. The experimental results confirm the general trend in solubility dependencies for common oil field scales at these conditions. At higher temperatures the deposition of CaCO3, CaSO4 and SrSO4 scale increases and the deposition of BaSO4 scale decreases since the solubilities of CaCO3, CaSO4 and SrSO4 scales decreases and the solubility of BaSO4 increases with increasing temperature. Key words: Scaling problems; solubility of scale; high salinity; high barium

The Interior Ballistic Research for Gas-Steam Launching System with Water Injection in Block

2012 ◽  
Vol 232 ◽  
pp. 765-769
Author(s):  
Jun Hua Bai ◽  
Chun Bo Hu ◽  
Jia Ming Li
Keyword(s):  
Energy Loss ◽  
Calculation Result ◽  
Water Mass ◽  
Water Injection ◽  
Large Angle ◽  
Cooling Water ◽  
Theory Analysis ◽  
Good Design ◽  
Injection Water ◽  
Simulation Results

Gas-steam launching system with water injection in block can overcome the problem of horizontal or large-angle launching, and gets more and more value in recent years. Based on the characteristic of launching system, the model was built with several assumptions, which could provide reference and technique for developing the new launching system. And the generator result was verified by the experimental one. The interior ballistic characteristics were researched by calculation result under different deep and injection water mass conditions. The comparison of the simulation results and theory analysis indicates the model was rational and valid, and different launching deep and cooling water mass had effect on ballistics, more water can cool down the silo, but also brings more energy loss, and deeper launch needs more energy, so good design is required to fit the parameters demand in all respects.

scholarly journals Design method and application of accurate adjustment scheme for water injection wells around adjustment wells

2021 ◽  
Author(s):  
Tongchun Hao ◽  
Liguo Zhong ◽  
Jianbin Liu ◽  
Xiaodong Han ◽  
Tianyin Zhu ◽  
...  
Keyword(s):  
Production Efficiency ◽  
Design Method ◽  
Water Injection ◽  
Oil Field ◽  
Productivity Index ◽  
Injection Wells ◽  
Wellhead Pressure ◽  
Production Wells ◽  
Drilling Operations ◽  
The Impact

AbstractAffected by the surrounding injection and production wells, the formation near the infill adjustment well is in an abnormal pressure state, and drilling and completion operations are prone to complex situations and accidents such as leakage and overflow. The conventional shut-in method is to close all water injection wells around the adjustment well to ensure the safety of the operation, but at the same time reduce the oil field production. This paper proposes a design method for shut-in of water injection wells around adjustment wells based on injection-production data mining. This method uses water injection index and liquid productivity index as target parameters to analyze the correlation between injection and production wells. Select water injection wells with a high correlation and combine other parameters such as wellhead pressure and pressure recovery speed to design accurate adjustment schemes. Low-correlation wells do not take shut-in measures. This method was applied to 20 infill adjustment wells in the Penglai Oilfield. The correlation between injection and production wells was calculated using the data more than 500 injection wells and production wells. After a single adjustment well is drilled, the surrounding injection wells can increase the water injection volume by more than 5000 m3. This method achieves accurate adjustment for water injection wells that are high correlated with the adjustment well. Under the premise of ensuring the safety of drilling operations, the impact of drilling and completion on oilfield development is minimized, and oilfield production efficiency is improved. It has good application and promotion value.

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