Water Coning Prediction: An Evaluation of Horizontal Well Correlations

Okon, Anietie N.

doi:10.11648/j.eas.20180301.14

Cited by 3 publications

(1 citation statement)

References 12 publications

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“…Due to the commonality of this problem and its effect on production, much work has been conducted for better understanding of the water-cresting phenomenon. The research on the topic of water-cresting thus far broadly encompassed the theoretical modeling, − numerical evaluation, − and experimental mechanistic studies, , with most of the research focused on the prediction of the critical rate for postponing the water-cresting phenomenon. In 1946, Muscat proposed the first analytical solution modeling the movement of the water–oil interface as a function of the well spacing, ratio of horizontal and vertical permeability, pay thickness, and well penetration for a vertical well in an aquifer-drive reservoir .…”

Section: Introductionmentioning

confidence: 99%

Field Validation of a Non-logging Alternative Method for the Prediction of the Location of Water-Cresting in Horizontal Wells for Water-Drive Reservoirs

Yue

et al. 2021

ACS Omega

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A previously reported method for a non-logging alternative method for the prediction of the location of water-cresting in horizontal wells for water-drive reservoirs is validated in a field test for the first time in this study. Using this method, the wellbore trajectory, variation in the reservoir permeability, and the pressure gradient data were used to calculate what is called the breakthrough coefficient for the different segments along the length of a set horizontal well with the largest calculated breakthrough coefficient corresponding to the most likely location of the actual water-cresting occurrence. This method was field-validated and found to be in good agreement with log testing for a group of seven wells in an oilfield in Northern China. Another calculated parameter derived from the breakthrough coefficient which is called the variation of the breakthrough coefficients that characterize the effect of the variation of water production along the length of the horizontal well due to the effect of the variation of the wellbore trajectory, permeability, and pressure gradient on the oil production is also introduced. This field validation found variation of the breakthrough coefficients to be weakly and inversely correlated to the oil production in application to a group of 27 wells in the same field.

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Section: Introductionmentioning

confidence: 99%

Field Validation of a Non-logging Alternative Method for the Prediction of the Location of Water-Cresting in Horizontal Wells for Water-Drive Reservoirs

Yue

et al. 2021

ACS Omega

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3D numerical simulation of clastic reservoir with bottom water drive using various ior techniques for maximizing recovery

Sharma

Kumar

Gupta

2018

J Petrol Explor Prod Technol

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In most reservoirs with oil rims, as the production begins, the gas-oil and oil-water fluid interfaces start deforming because of the imbalance between viscous and gravitational forces, leading to coning or cusping. This can be overcome using proper withdrawal rate, offset from water-oil contact and horizontal length. Further smart horizontal wells require optimization of nozzle size and compartment length also. To see the effect of these parameters on recovery, a three-dimensional geological model of a clastic reservoir from Upper Assam Basin has been used. This model was history matched for a period of 16 years on 46 wells. After successful validation of model on field scale and well level, performance prediction was carried out to see the effect of withdrawal rate, offset from water-oil contact, horizontal length, compartment length and nozzle size using vertical/horizontal and ICD completion. From the analysis, it is evident that application of advanced well completion, ICD, is suitable for such reservoir. Depending on the scenario, maximum cumulative oil production was obtained from ICD wells with 1.08 MMm 3 compared to vertical well with cum oil production of 0.63 MMm 3 . Economic analysis has been carried out for the examined scenarios.

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Gas to Wire Or Gas to Shore: Evaluation of Transitional Clean Energy in Offshore UKCS

Mistry

Wahid

Fitch

2020

Day 3 Wed, October 28, 2020

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Gas to Wire (GTW) is a concept which will aid the UK to meet their growing energy demand as, GTW will allow marginal and somewhat depleted gas fields to convert natural gas to electricity onsite, with the electricity exported via subsea power cables - the concept is not yet fully commercialised offshore. This paper initially discusses what is GTW and then investigates two separate cases: the first focuses on evaluating the viability of GTW for the Kumatage gas field which is 78 km close to shore (located in the Southern North Sea) (Figure A1), by assessing the fields production potential and profitability. The second case will evaluate a standard practice of gas sales. Reservoir data was provided by the company who own the field. The first case was split into three stages. The first stage reviews the sensitivity analyses completed to generate the base sand box model representative of the Kumatage field using a pre and post processing package. Multiple sensitivities such as: well depth, vertical versus horizontal wells and production rates were then conducted on this sand box model in order to develop a base case development strategy. Secondly, from the base model, the subsequent production data for GTW and gas sales was then fed into an economic evaluation of the two cases using commercial project modelling software. Upon determining the optimum case, necessary well completions required to maintain a steady production rate over the life of the field, currently defined as 20 years by the current operator, were explored. Finally, further analysis of the field was conducted to assess whether heterogeneities impact the overall recovery of the field at different gas production rates. Six further geological realisations were constructed to assess this. By examining the results from these three stages, it was found that although gas sales is more profitable in Kumatage, GTW is viable. A combined-cycle gas turbine efficiency of 50% in conjunction with an electricity price of approximately $26/MWh (NPV10 for 100% base load) is required -particularly for a gas production rate of 40 MMScf/day. The results and analysis in this paper also show that heterogeneity had a minimal impact on ultimate recovery. Heterogeneity was modelled by the inclusion of a shale barrier, whose thickness is uncertain, and by varying the porosity and permeability of the Unit A and B sands. A discussion is also included in GTW's potential to work in conjunction with renewable technologies, such as tying back to Hornsea Project Four which is an offshore windfarm currently under the preapplication stage by Ørsted (hornseaprojects, 2019). It will be approximately 65 km from the Yorkshire coast and will be close to the Theddlethorpe and Bacton gas terminals (National Grid, 2019). By doing so, the electricity produced from Kumatage would need to be exported via a power cable to the windfarm. This study also discusses GTWs compatibility with existing renewable technologies to reduce carbon dioxide (CO2) emissions. By combining the findings of this paper, a further review of the potential of GTWs ability to unlock more marginal and stranded assets and contributing to the security of future UK energy supply. What can also be explored further from this paper is multiphase flow in the reservoir to then be able to model GTW to other offshore gas fields in the SNS.

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Water Coning Prediction: An Evaluation of Horizontal Well Correlations

Cited by 3 publications

References 12 publications

Field Validation of a Non-logging Alternative Method for the Prediction of the Location of Water-Cresting in Horizontal Wells for Water-Drive Reservoirs

Field Validation of a Non-logging Alternative Method for the Prediction of the Location of Water-Cresting in Horizontal Wells for Water-Drive Reservoirs

3D numerical simulation of clastic reservoir with bottom water drive using various ior techniques for maximizing recovery

Gas to Wire Or Gas to Shore: Evaluation of Transitional Clean Energy in Offshore UKCS

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