The Issaran field located 200 km east of Cairo-Egypt, is a heavy oil reservoir. The oil is of 8-12 degree API with viscosity of 4000 cps at standard conditions. Productivity of the wells has sharply declined due to increase in the water cut and increase in the formation skin value. The problem is attributed to the heterogeneity of the reservoir together with presence of fractures which is causing poor sweep efficiency plus the accumulation of hydrocarbon deposits. The major challenge to remedy this situation was; 1) The creation of new extended flow channels. 2) Accurate placement of the treatment. 3) Diversion within the reservoir. 4) Provide sustain production increase. And 5) The flow and the production of oil through the newly formed wormholes. A new innovative approach using a combination of acid based treating fluids and steam were used. Acid in combination with fit for purpose chemical diverting agent plus selective placement mechanism succeeded to open new production horizons and stimulate the existing one. The Addition of Steam has succeeded in reducing the viscosity and increasing the mobility of oil, and also in providing pressure support to the reservoir achieving further increase in the benefits of the acid stimulation. The results of the treatments carried out so far have provided a new dimension in the enhanced recovery process of the heavy oil. This paper explains the design, execution, evaluation and the recommended way forward of this world first acid & steam production enhancement initiative for enhanced recovery process in the heavy oil reservoirs.

Munga field of the Greater Nile Petroleum Operating Company (GNPOC) in Sudan has several wells that have commingle production from the Aradeiba, Bentiu-1 and Bentiu-2 formations. These formations are highly variable in terms of the reservoir properties, oil types and pressure regimes. Because of the contrast properties of different layers, the water cut phenomenon is relatively fast and severe which hampers the productivity and ultimate recovery of the individual well as well as the field.For effective Reservoir Management and to limit the declining trend of the field, Water Management Techniques are applied in some of the wells of this field. Information obtained in the process was used for reservoir model calibration, well productivity prediction, low productivity diagnosis, and generation of new drainage points and remedial action for water management. This paper discusses the technical details of three cases corresponding to the wells Munga-XX and Umm Sagura South-XX (USS-XX) and Munga-XY in which, a multidisciplinary approach has been implemented in order to determine depletion profile, produced oil and remaining reserves, locate any "by-passed" oil zones, determine oil and water contributions from each zone and shut off the excess water production while maintaining or increasing oil production.

For the last several years, viscous pills, polymer based, were used to kill the wells during the workover operation in the tronian formation existing in the eastern desert of Egypt. These polymer pills have negatively affected the wells productivity by blocking the pore throats and reducing the permeability. As an example, the well A-1 was producing 300 bpd (Gross) which declined dramatically after a workover operation which included the viscous polymer pills to produce only 20 bopd. An engineering study was carried out to identify the main reason for the decline in the production. Several experiments were performed in the lab in order to simulate the filter cake using formation samples and evaluate the effect of the polymer being injected on the sandface permeability. An engineered solution was designed to break the polymer subsequently pumped in the formation and stimulate the matrix in order to recover and enhance the oil production. The remedial work was executed using a Fiber Optics Telemetry Enabled Coiled Tubing (FOTECT) system to optimize the treatment leveraging on downhole real time measurements. This paper describes the first application of FOTECT in sandstone formations, involving: 1. The sandstone matrix stimulation operation. 2. Measuring both bottom hole pressure and temperatures at static and dynamic conditions during the entire operation. 3. Accurate depth correlation to achieve optimum placement of the treatment fluids 4. Monitor the chemical reactions in real time of the engineered treatment fluid. 5. Monitor the diversion performance during Sand Stone stimulations and the timing required for efficient reactions. 6. Qualitative production allocation of the interval as a response to the treatment fluids 7. Evaluation of the skin value real-time while executing matrix stimulation. 8. Pressure transient analysis in real-time enabling the standard output of a well test (permeability, skin, Pressure, and reservoir boundaries). The experience demonstrates that use of real-time downhole measurements during the CT treatment allows: a) the evaluation of the well performance before and after the treatment, b) enables optimization of the treatment as it is executed, based on the formation response, enhancing the chance for a successful intervention, and c) provides an added alternative to perform a well testing operation right after the treatment, thus, obtaining valuable information to update the reservoir model.

For the last several years, viscous pills, polymer based, were used to kill the wells during the workover operation in the tronian formation existing in the eastern desert of Egypt. These polymer pills have negatively affected the wells productivity by blocking the pore throats and reducing the permeability. As an example, the well A-1 was producing 300 bpd (Gross) which declined dramatically after a workover operation which included the viscous polymer pills to produce only 20 bopd. An engineering study was carried out to identify the main reason for the decline in the production. Several experiments were performed in the lab in order to simulate the filter cake using formation samples and evaluate the effect of the polymer being injected on the sandface permeability. An engineered solution was designed to break the polymer subsequently pumped in the formation and stimulate the matrix in order to recover and enhance the oil production. The remedial work was executed using a Fiber Optics Telemetry Enabled Coiled Tubing (FOTECT) system to optimize the treatment leveraging on downhole real time measurements. This paper describes the first application of FOTECT in sandstone formations, involving: The sandstone matrix stimulation operation.Measuring both bottom hole pressure and temperatures at static and dynamic conditions during the entire operation.Accurate depth correlation to achieve optimum placement of the treatment fluidsMonitor the chemical reactions in real time of the engineered treatment fluid.Monitor the diversion performance during Sand Stone stimulations and the timing required for efficient reactions.Qualitative production allocation of the interval as a response to the treatment fluidsEvaluation of the skin value real-time while executing matrix stimulation.Pressure transient analysis in real-time enabling the standard output of a well test (permeability, skin, Pressure, and reservoir boundaries). The experience demonstrates that use of real-time downhole measurements during the CT treatment allows: a) the evaluation of the well performance before and after the treatment, b) enables optimization of the treatment as it is executed, based on the formation response, enhancing the chance for a successful intervention, and c) provides an added alternative to perform a well testing operation right after the treatment, thus, obtaining valuable information to update the reservoir model.

Water Injection is considered to be one of the most important ways to enhance oil recovery. Although all of the Injector wells in Rahma field in Egypt were stimulated before using hydraulic fracturing however, they were still suffering from severe decrease in the injection rates which are far below the target. As a first time to be done for Qarun Petroleum Company (QPC), a full technical study has been done to the field in order to identify the main reason for the severe decrease in the injection profile which was formation damage and high increase in the skin value. Based on the study done, a technical treatment was designed and Matrix Stimulation Engineering was implemented to the well Rahma-12 as the first candidate for Matrix Stimulation. The results were successful, the injection rate increased in the well Rahma −12 from 280 bwpd to 3000 bwpd and in the well Rahma-10 from 300 bwpd to 2800 bwpd. These successful results encouraged QPC to implement the Matrix Stimulation treatment in all the injector wells in the Rahma field which resulted in great enhancement to the injection profile in the field. This paper discusses the full technical study done to the field and the chemical tests done in the lab in order to design the best treatment to the formation. It shares the experience gained during the execution phase and new best practices that were implemented first time which resulted in a great success. Finally it provides a useful data base for the field and the Matrix Stimulation Operations which were done first time in QPC fields.