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Streamline Simulation Study on Recovery of Oil by Water Flooding: a Real Case Study on Haripur Field

Mohammad Amirul Islam
Department of Geology, University of Dhaka, Dhaka-1000, Bangladesh

A.S.M. Woobaidullah
Department of Geology, University of Dhaka, Dhaka-1000, Bangladesh

Badrul Imam
Department of Geology, University of Dhaka, Dhaka-1000, Bangladesh

Abstract/ Executive Summary:

Haripur field is the first oil producing field in Bangladesh. The field produced approximately 0.53 MMSTB of oil from the well No. SY-7. The oil production began in 1987 and terminated in 1994. All of the oil was produced by the reservoir own energy from the depth of 2030 meter. Recent investigation and study have revealed that approximately 31 MMSTB Oil is remaining in that formation as validated by the reservoir performance based study i.e. oil production rate and tube head pressure history matching. At present condition, the reservoir has no pressure energy to lift the oil to surface as it requires minimum 1500 psi pressure, so it needs pressure energy to lift the oil to surface. Among the recent developed technologies water injection is one of the best methods to sweep oil towards the production well from the injection well as well as to provide sufficient pressure for lifting. In this study we proposed design for optimum waterflooding pattern and defined optimum number of injection and production wells. In addition the production and injection rates are optimized along with selection of the best placement of production and injection wells and their life.

Keywords: Reserve, Resources, Water flooding, Streamline simulation, Streamline derived

Location: Greater Sylhet, Bangladesh

Start Date: 00-00-1987

End Date: 00-00-1994

Program Area: Resource Development and Management

Commodity: Waterlogging

Objectives:

i) To determine (near) optimal individual well rates that are sustainable (subject to constraints, such as gradual changes over time as well as globally maximum/minimum total fluid rate handling capacities). and

ii) To reduce the computational costs, we made use of streamline derived information to drive the well rate changes while also taking advantage of the computational efficiency of streamline simulation itself, which is generally well-suited for modeling waterfloods.

Methodology:

The Sylhet structure was delineated by Pakistan Petroleum Limited (PPL) after recording single-fold seismic data. Gas was discovered in 1955 by drilling Sylhet-1 well, which was the first gas discovery well in Bangladesh. Unfortunately, the well blew out leaving a crater. Subsequently, five more wells, Sylhet-2 to Sylhet-6, were drilled during the period from 1956 to 1964. Sylhet-4 blew out upon reaching 315 m and Sylhet-5 was drilled in 1963 as an observation well up to a depth of 575 m. Sylhet-6 was drilled in 1964 up to a depth of 1,405 m and was completed as a dual producer. Sylhet-7 was drilled in 1986 as a gas development well but turned out to be the first oil discovery well. Surma-1 and the sidetracked well Surma-1A were drilled in 1989 to appraise the oil discovery (www.sgfl.org.bd). A reservoir simulation model characterizes the reservoir by integrating the static geological model and the dynamic flow model populated with actual reservoir performance data such as pressures, tests, production rates, inter fluid-rock characteristic curves characterized by the capillary and relative permeability curves, PVT data, etc. (Caers et al. 2002).There are geocellular reservoir model of static reservoir condition and conventional, compositional, thermal and streamline reservoir simulation model of dynamic reservoir condition (Aziz and Settari 1979). The structural model has been constructed by 94 cells ×83 cells × 74 cells in I,J and K directions, altogether 577348 grid cells among them Bhuban Formation is in from 69 to 74 simulation layers where 31 MMSTB of oil remains as depicted. Developing a meaningful reservoir model capable of generating reliable results with reasonable certainty requires a multidisciplinary team with appropriate technical skills and broad experience. Once a reasonably good history match is obtained, the model can be used to predict production and injection profiles, infill wells, well workovers, stimulation, and other requirements according to specified prediction guidelines (related to drilling, well completions, production engineering and reservoir management, including vertical flow and surface flow systems) under various “what if” conditions for reservoir development, production and management strategies. Based on a comparative economic analysis, the optimum development and producing strategy can be selected for implementation. Depending on the amount and quality of performance data available, the projected cumulative production to the economic limit with this optimum strategy should establish the most likely estimated ultimate recovery (EUR). Based on the extensive log, core, and testing data obtained over the past 12 years (discovery year, 2-year appraisal period followed by a 3-year initial development and a 7-year of production periods), a 0.5 million-cell geo-cellular model was built and used to estimate an OIIP of about 31.53 MMSTB. Based on this most likely or best 3D geological realization (with an OIIP estimate of 31.53 MMSTB), a related integrated 3D and three-phase reservoir simulation model was developed by a multidisciplinary team and used to match this extensive reservoir performance history covering a period of 7 years with 0.53 MMSTB (1.68% OIIP) produced. This history-matched black-oil model was used to predict future reservoir performance under the ongoing base-case operations using peripheral waterflood, including economically justified well workovers, infill drilling, and well completions to better manage the decline based on to recover 31 MMSTB of oil remain as contingent resources in 2015. Streamline simulation is being increasingly used for managing waterflood operations in some of the largest fields in the world. Underpinning the analysis of a waterflood is the relationship between injection and production wells. This relationship can be directly and fully quantified on reservoir models through streamlined simulation as is clear. This ability to streamline simulation is unique. In the past, engineers have used time-consuming trial and error methods to optimize waterflood simulations using streamlined data. In this study, we discuss the use of Pattern Flood Management. This option provides an automated way of optimizing streamline waterflood simulations. The techniques currently used are standard reservoir engineering methods. At the end of simulation the streamline flux for oil production rate of water injection wells I2, I3, I4 and I5 remain sharp. All of the lines show value 0.01 STB/D by green line depicted. 10. The water front is still near the injection wells. At the end of simulation injected water flows through the porous permeable formation with 0.0001 STB/D. 20 far from the injector indicating water is advancing towards the production well. Water flow stream is leveled by the blue line and the front is indicated by the separation point between blue and yellow color stream. Injector I5 arrived at its breakthrough point whereas others remain far away from a breakthrough. The fractional flow of water is defined

Source of Information: Bangladesh J. Sci. Res. 28(1): 61-72, 2015 (June)

Article Link (Online Journal):

Funding Source:

Budget:

Total Budget (Tk.) :

Achievement/Findings:

Oil recovery becomes very challenging with respect to the technical and commercial point of view as uncertainty and risk exist behind the recovery project. It is a good news that invent of several recovery techniques and modeling with very power full computer simulator reduces the uncertainty and risk making the recovery project technically and commercially feasible. In this study, 31 MMSTB of oil remaining in the reservoir after production of 0.53 MMSTB of oil is recoverable by water flooding through five injection and one production wells. It is predicted that 1.66 MMSTB of oil can be recovered by injecting 7.38 MMSTB of water over ten years. It is possible to recover the residual oil also after water flooding by capillary displacement method such as surfactant flooding.

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