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Abstract Reliable production forecasting of all fluid streams involved in hydrocarbon production has remained a perennial problem in the oil and gas industry. This paper presents the methodology and results of an improvement to the water forecasting approach adopted in the management of all the producing fields and reservoirs of OML-ZZZ located in the Niger Delta area of Nigeria. The main objective of our study was to identify and evaluate a means of achieving water/liquid forecast that is representative of field observed trends – a key input for the sizing of planned water dehydration facilities for our fields. Our study made use of an integrated production forecasting solution model with the associated engineering and geoscience data, which optimizes on oil production while forecasting the other fluid streams subject to defined system constraints. Improvement in water forecast was achieved through a review of the abandonment conditions of quit wells which have already reached their abandonment as analogues for producing wells being forecasted. Based on the review, we identified and applied recommended tranches of BSW conditions which have enabled better and more realistic forecasts of gross liquid and water production. The benefits of these improved forecasts include an increase in oil volumes and proper equipment/facilities sizing among others.
- Reservoir Description and Dynamics > Improved and Enhanced Recovery (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Production forecasting (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring (1.00)
- Production and Well Operations > Well Operations and Optimization > Produced water management and control (0.94)
Abstract Pressure transient tests have been used for many years for the determination of well and reservoir parameters. Initially analyses of the tests were limited to evaluation of well performance. With the introduction of computer and pressure derivative log-log plots, numerous signatures of well reservoir and boundary responses are diagnosed and their model parameters estimated. Of recent, controlled reservoir monitoring from either permanent downhole gauges or standard bottom-hole pressure tests especially in gas reservoirs show that gas-water contact movement can be detected from the late time pressure derivative responses hence, water breakthrough time could be predicted. For a historical pressure transient tests taken at different times, the superimposition of their different pressure derivatives on the same log-log plot enable detection of advancing water front. The estimated fluid contacts from subsequent tests can be used to calculate gas volumes/reserves and predict water breakthrough time for the gas wells. This process was applied in Galaxy North field. The Field is a major domestic gas supplier for power generation in Nigeria and it started production in Dec 1963 with oil wells, while the gas wells came on-stream in 1984. Four gas wells have been drilled to in the field date. Current production is at 10Mbopd and 50MMscf/d from oil/gas and gas reservoirs. Pressure transient test are routinely carried out in the field to understand reservoir dynamics and gas wells performances and to ensure proper production planning towards uninterrupted gas supply to domestic market. The pressure transient tests carried out in Galaxy North wells between 2004 and 2013 depicted responses characteristic of upward trend (pseudo no-flow boundary). The boundary was established to be due to the effect of advancing gas/water contact. The estimated gas/water contact was compared with open-hole saturation log of an infill well drilled in June 2012 and results were close. This was used tovalidate the results of the pressure transient analyses. This paper presents guidelines and best practices on the use of classical reservoir tools in monitoring the gas water contact and the information derived could be used in estimating gas reserves and predict the future performance of the gas wells to ensure effective gas delivery to customer.
- Africa > Nigeria (0.68)
- Asia > Middle East > Qatar > Arabian Gulf (0.61)
- North America > Trinidad and Tobago > Trinidad > North Atlantic Ocean > Columbus Basin (0.99)
- Asia > Middle East > Qatar > Arabian Gulf > Rub' al Khali Basin > North Field > Laffan Formation (0.99)
Abstract Operating envelopes are used in many industries, including the oil industry, to define appropriate operating boundaries and limits for production systems. In the oil industry, the boundaries generally include minimum and maximum operating rates, as well as minimum and maximum operating pressures and temperatures for the different components of the production system. Today, the use of operating envelopes has been extended to the subsurface (specifically hydrocarbon-bearing reservoirs) with the aim of identifying optimum limits for production rates and reservoir pressure depletion. The Sofad field is one of the biggest and most structurally complex oil fields in the Western Niger Delta straddling land, swamp and shallow offshore. The high offtake rates from the reservoirs, coupled with the high fault density, have inhibited the response of the otherwise active aquifer especially in the key producing reservoirs. As a result, the key reservoirs have suffered severe pressure depletion over the years. Analyses of the historical production/pressure trends of these reservoirs clearly indicate that the reservoir pressures are generally sensitive to the rates of production from the reservoirs. Thus, it became essential to evaluate the maximum production rates for these reservoirs in order to manage the reservoir pressure depletion and consequently maximise oil recovery (pending the execution of the water injection project for pressure maintenance). This paper presents how the operating envelopes for the reservoirs were designed. It also showcases how the operating envelopes are being used in ensuring the maintenance of reservoir pressures, which has led to an improvement in the recovery from these reservoirs over the last 3 years (2010 – 2012).
- Oceania > Papua New Guinea > Papuan Peninsula > Central Province > National Capital District > Petroleum Retention License 15 > P’nyang Field (0.97)
- Oceania > Papua New Guinea > Papuan Peninsula > Central Province > National Capital District > Petroleum Retention License 15 > Elk-Antelope Field (0.97)
- Oceania > Papua New Guinea > Papuan Peninsula > Central Province > National Capital District > Petroleum Retention License 15 > Angore Field (0.97)
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