Multiwell Interference Test in the Colville River Field, Alaska

Erwin, Mike; Sanders, L.; Redman, R.

doi:10.2523/77453-ms

Cited by 6 publications

(3 citation statements)

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“… Landa et al [2000] combine pressure, log, core, and geological data to obtain a reservoir description (permeability map) for the Pangerungan field in Indonesia. By showing the influence of conductive faults, Erwin et al [2002] demonstrate the pitfalls of relying on geostatistical and structural representations of the reservoir and of ignoring its internal architecture [ Fogg , 1986, 1990; Webb and Anderson , 1996; Williams , 1988].…”

Section: Geology and Testingmentioning

confidence: 99%

“…These ideas may be used under a variety of circumstances including the evaluation of pumping tests by hydraulic tomography [see Bohling et al , 2002]. I demonstrate this point by considering the example given by Erwin et al [2002]. The study involved the evaluation of pulse test responses from two wells at seven other locations.…”

Section: Inversion Algorithmmentioning

confidence: 99%

“…The reservoir is a shallow marine sandstone consisting of very fine grained sediments of the Jurassic age. The challenges of using data based on static measurements are discussed by Erwin et al [2002]. Figure 14 presents results where the responses at all wells were evaluated simultaneously (V. Q. Phan, personal communication, 2001).…”

Section: Inversion Algorithmmentioning

confidence: 99%

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A review of applications to constrain pumping test responses to improve on geological description and uncertainty

Raghavan

2004

Reviews of Geophysics

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[1] This review examines the single-phase flow of fluids to wells in heterogeneous porous media and explores procedures to evaluate pumping test or pressure-response curves. This paper examines how these curves may be used to improve descriptions of reservoir properties obtained from geology, geophysics, core analysis, outcrop measurements, and rock physics. We begin our discussion with a summary of the classical attempts to handle the issue of heterogeneity in well test analysis. We then review more recent advances concerning the evaluation of conductivity or permeability in terms of statistical variables and touch on perturbation techniques. Our current view to address the issue of heterogeneity by pumping tests may be simply summarized as follows. We assume a three-dimensional array (ordered set) of values for the properties of the porous medium as a function of the coordinates that is obtained as a result of measurements and interpretations. We presume that this array of values contains all relevant information available from prior geological and geophysical interpretations, core and outcrop measurements, and rock physics. These arrays consist of several million values of properties, and the information available is usually on a very fine scale (often <0.5 m in the vertical direction); for convenience, we refer to these as cell values. The properties are assumed to be constant over the volume of each of these cells; that is, the support volume is the cell volume, and the cell volumes define the geologic scale. In this view it is implicit that small-scale permeability affects the movement of fluids. Although more information than porosity is available, we refer to this system as a ''porosity cube.'' Because it is not economically possible to carry out computations on a finescale model with modern resources on a routine basis, we discuss matters relating to the aggregation and scale-up of the fine-scale model from the perspective of testing and show that specific details need to be addressed. The focus is on single-phase flow. Addressing the issue of scale-up also permits us to comment on the application of the classical or analytical solutions to heterogeneous systems. The final part of the discussion outlines the inversion process and the adjustment of cell values to match observed performance. Because the computational scale and the scale of the porosity cube are different, we recommend that the inversion process incorporate adjustments at the fine scale. In this view the scale-up process becomes a part of the inversion algorithm.

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Section: Geology and Testingmentioning

confidence: 99%

Section: Inversion Algorithmmentioning

confidence: 99%

Section: Inversion Algorithmmentioning

confidence: 99%

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A review of applications to constrain pumping test responses to improve on geological description and uncertainty

Raghavan

2004

Reviews of Geophysics

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Early Field Life Interference Pulse Test Design to Refine Reservoir Uncertainties: A Reservoir Surveillance Opportunity for the Wheatstone Gas Field, Australia

Flett

Müller

2016

SPE Asia Pacific Oil &Amp; Gas Conference and Exhibition

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The initial well proving and early production period of a hydrocarbon field is a valuable and unique period of field surveillance where there is the opportunity to narrow the range of uncertainty for key reservoir properties through the use of inter-well interference testing. The Wheatstone gas field, currently being developed as part of the Wheatstone liquefied natural gas (LNG) project, is located offshore north-western Australia. The start-up of the Wheatstone field, due to the nature of constrained ramp-up for LNG supply and location of development wells provides a unique opportunity for early field life interference testing. This is due to periods of individual well and well combination flows that are ideal for pulse generation and detection, with many development wells observing potential pressure responses while nearby wells are flowing. This paper will focus on the potential of initial well proving flows for pulse testing at the Wheatstone field to capture reservoir information. Pulse testing can potentially be an important reservoir diagnostic tool, particularly during early production when the field is at initial state. Through considered test design strategy, detection of a pressure pulse in an observed well can be used to infer inter-well reservoir connectivity, connected pore volume and transmissibility. This paper provides a method to refine reservoir pore volume ranges and transmissibility. This will be accomplished through the use of dynamic model derived pulse testing type curves using homogeneous reservoir properties to match observed signals for selected active and observation well pairs within the Wheatstone field. A suite of dynamic models exist for the Wheatstone field. These models cover a wide range of possible realisations for reservoir outcomes that affect initial static volumes and dynamic responses including structure, reservoir net to gross ratio and petrophysics (porosity, permeability and saturation). Selected dynamic models that reflect the uncertainty in inter-well connectivity, driven by variations in net to gross ratio and petrophysics, were run to develop well proving profiles for selected development wells, with non-active wells observing for a pressure pulse from this activity. Following the reservoir simulation uncertainty study of well proving flows, a homogeneous reservoir property simulation model was developed based on the reference mid case dynamic model, with constant porosity and permeability applied to active reservoir cells in the mid model. A variety of type curve pulse responses were developed for a range of porosity and permeability ranges for well pairs. These homogeneous type curves are then used to match reservoir model responses for the well proving uncertainty study, leading to estimates of potential average pore volume and permeability between well pairs. Thus the use of homogeneous reservoir model matching of interference signals during initial field conditions can be employed to appraise inter-well reservoir property ranges.

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A New Methodology for Naturally Fractured Reservoir Characterization: Use of Multi-Well Interference Tests Interpretation

Vincent¹,

Portier²

2020

SPE Europec

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Reservoir characterization is a key aspect during the appraisal and production phases of a field development. Understanding the reservoir property distribution and dynamic behavior reduces uncertainties and helps to improve recovery while optimizing investments. Modern seismic and logging tools, combined with core data, provide multi-disciplinary teams with better data quality. However, the reservoir heterogeneity and connectivity, often remain uncertain until several years of production have been achieved. This is true of naturally fractured reservoirs, for which fracture connectivity can only be characterized dynamically. In order to provide earlier dynamic connectivity information in a field development, interference tests have been developed to define whether parts of a reservoir are in communication, and to estimate reservoir properties between wells which is not possible from log measurements and correlations. Interference tests are ideally conducted when a reservoir is in equilibrium with homogeneous and fully stabilized pressure through the entire field. This paper describes a new methodology for interference test interpretation when reservoir pressure is not stabilized, and also describes how to optimize multi-well interference operation sequencing. First, the observation well is tested, and second, active wells are produced in a sequence while the observation well bottom hole pressure (BHP) is still building up. Pressure changes only related to the interference are extracted from the pressure measurements at the observation well by removal of the build-up effects. Interpretation is subsequently performed to quantify reservoir properties such as matrix and fracture permeability and porosity to match interference time lag (also named time of flight), pressure and depletion amplitude. Permeability anisotropy and fracture connectivity are defined and quantified at the field scale. The application of this new methodology to multi-well interference tests performed on a naturally fractured gas reservoir is presented in this paper. Using this methodology can prove connectivity through open natural fractures and quantify the fracture network properties even when there is a very small interference amplitude. Defining the extent of a natural fracture network and its contribution to the hydrocarbon production is crucial for naturally fractured reservoir development and reservoir management. In addition the described methodology was applied to calculate gas volumes dynamically connected to the wells. The capability to interpret an interference test performed while the pressure measured at the observation well is still building up allows a significant operational time and cost reduction while ensuring accurate interpretation of reservoir parameters. This methodology can be applied to an interference test including a well pair or multiple wells.

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Multiwell Interference Test in the Colville River Field, Alaska

Cited by 6 publications

References 0 publications

A review of applications to constrain pumping test responses to improve on geological description and uncertainty

A review of applications to constrain pumping test responses to improve on geological description and uncertainty

Early Field Life Interference Pulse Test Design to Refine Reservoir Uncertainties: A Reservoir Surveillance Opportunity for the Wheatstone Gas Field, Australia

A New Methodology for Naturally Fractured Reservoir Characterization: Use of Multi-Well Interference Tests Interpretation

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