EP3701119B1 - Conception de puits et structure de puits associèe - Google Patents

Conception de puits et structure de puits associèe Download PDF

Info

Publication number
EP3701119B1
EP3701119B1 EP18797061.1A EP18797061A EP3701119B1 EP 3701119 B1 EP3701119 B1 EP 3701119B1 EP 18797061 A EP18797061 A EP 18797061A EP 3701119 B1 EP3701119 B1 EP 3701119B1
Authority
EP
European Patent Office
Prior art keywords
well
well completion
inflow area
wellbore
effective
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Active
Application number
EP18797061.1A
Other languages
German (de)
English (en)
Other versions
EP3701119B8 (fr
EP3701119A1 (fr
Inventor
Michael Byrne
Lesmana DJAYAPERTAPA
Ken Watson
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Lloyds Register Digital Products Ltd
Original Assignee
Lloyd's Register Group Ltd
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Lloyd's Register Group Ltd filed Critical Lloyd's Register Group Ltd
Publication of EP3701119A1 publication Critical patent/EP3701119A1/fr
Application granted granted Critical
Publication of EP3701119B1 publication Critical patent/EP3701119B1/fr
Publication of EP3701119B8 publication Critical patent/EP3701119B8/fr
Active legal-status Critical Current
Anticipated expiration legal-status Critical

Links

Images

Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B41/00—Equipment or details not covered by groups E21B15/00 - E21B40/00

Definitions

  • Described examples relate to methods of well design, including well construction, associated well structures and, in particular but not exclusively, well completion arrangements for use in a well.
  • US2016153265 describes an algorithmic process for determining inflow control device (ICD) parameters along a horizontal well for optimizing production.
  • the process begins by building a model of a wellbore in a wellbore simulator. During this step, certain well and reservoir parameters such as, but not limited to, water cut, permeability, and skin models are configured in the wellbore simulator software.
  • the process executes an ICD optimization algorithm to determine the optimal ICD parameters.
  • These ICD parameters may include, but are not limited to, the number of ICDs for a wellbore, the placement of the various ICDs along the wellbore, and the types of ICDs being utilized.
  • the types of ICDs may cause varying pressure drops due to different hole densities, hole diameters, hole types, hole distance, number of holes, etc.
  • the method may comprise providing a computational model of a well. That computational model may comprise a section of wellbore and surrounding formation.
  • the model may comprise a well completion arrangement positioned between the wellbore and surrounding formation.
  • a well completion arrangement may define fluid paths between the surrounding formation and the wellbore. Those fluid paths may provide an effective inflow area between the surrounding formation and the wellbore.
  • the method may comprise calculating fluid flow between the surrounding formation and the wellbore, e.g. via the well completion arrangement. In some examples (e.g. production examples) this may include calculating fluid flow from the surrounding formation and the wellbore. In other examples (e.g. injection examples) this may include calculating fluid flow from the wellbore to the surrounding formation.
  • the method may further comprise varying the effective inflow area of the well completion arrangement.
  • the method may then comprise repeating the step of "calculating" and "varying", accordingly, which may permit determination of a profile of well performance for that computational model of the well, e.g. based on a range of effective inflow areas of the well completion arrangement. From that determined profile, a well design (e.g. optimal well design) may be provided (e.g. having a particular effective inflow area).
  • the method may comprise repeating the steps of calculating and varying so as to provide a profile of well performance across the range of effective inflow areas of the well completion arrangement, and whereby the effective inflow area of the desired well design (e.g. optimal well design) relates to a region associated with a point of inflection of the profile.
  • the effective inflow area of the optimal well design may provide for maximum fluid production/injection for that modelled wellbore and surrounding formation.
  • the determined effective inflow area may be between a lower inflow area threshold, for example below which the inflow area corresponds to that of well completion arrangements comprising inflow control devices for control of fluids, and an upper inflow area threshold, for example above which the inflow area corresponds to that of well completion arrangements configured as standalone screens.
  • the profile of well performance may be provided in terms of productivity index.
  • the modelled well completion arrangement may comprise a gravel pack, modelled to have an effective inflow area provided by that gravel pack.
  • the modelled well completion arrangement may comprise a plurality of inflow ports, defined through a well completion tubular or housing surrounding a base pipe, or the like.
  • the effective inflow area may be based on the number and size of the inflow ports. For examples, increasing the effective inflow area may be achieved by increasing the number of inflow ports, or the like.
  • At least one effective inflow area used in the range of effective inflow areas may be selected, such as initially selected, based on the diameter of the well completion tubular, and or the wellbore diameter.
  • the range of effective inflow areas may be selected based on one or more of: rate of desired fluid production, well length, or formation properties.
  • the computational model may comprise a plurality of well completion arrangements, axially aligned and connected lengthwise.
  • each well completion arrangement may be individually varied in order to determine the well design, e.g. optimal well design.
  • the well design may comprise at least a first well completion arrangement having a first effective inflow area and a second well completion arrangement having a second effective inflow area.
  • the second effective inflow area may be different from the first effective inflow area.
  • the number and/or size of inflow ports may be different between first and second well completion arrangements.
  • the computational model may comprise multiple well completion arrangements being modelled such that fluid is permitted to flow along the multiple well completion arrangements in an annulus provided between the modelled wellbore and surrounding formation.
  • the model may comprise sections without annulus packers, or the like.
  • the method may comprise associating a particular viscous resistance with the well completion arrangement and/or surrounding formation in order to calculate fluid production/injection, e.g. between the surrounding formation, via the well completion arrangement, to the wellbore.
  • the computational model of the well is a computational fluid dynamic (CFD) model.
  • Such a well design may have been determined using the method described.
  • Such a well design may be stored in a computer file (e.g. non-transitory medium or carrier), or may be provided in hardcopy format.
  • the well design may be an optimal well design (e.g. having a particular effective inflow area based on a determined profile).
  • Such a well design e.g. use of an optimal well design, for the design of a well.
  • Such a designed well may comprise well completion arrangements having effective inflow areas.
  • Such a method may comprise determining or using a well design (e.g. optimal well design having a well completion arrangement of a particular effective inflow area based on a profile of well performance, where the profile of well performance may have been determined from expected fluid production/injection based on a range of effective inflow areas.
  • the method may further comprise completing a section of well, e.g. by positioning the well completion arrangement between wellbore and surrounding formation.
  • a well comprising a section of wellbore, well completion arrangement and surrounding formation.
  • the well may be configured such that fluids are communicated between the surrounding formation, via the well completion arrangement, and the wellbore.
  • fluids When producing, fluids may be communicated from the surrounding formation to the wellbore.
  • injecting fluid may be communicated from the wellbore to the formation.
  • the well completion arrangement ay serve to define fluid paths between the surrounding formation and the wellbore, those fluid paths providing an effective inflow area between the surrounding formation and the wellbore.
  • the effective inflow areas may be provided so as to optimise well performance.
  • the effective inflow area of the well completion arrangement may provide maximum fluid production for that wellbore and surrounding formation.
  • the well completion arrangement may comprise a gravel pack, autopack, or the like, having an effective inflow area provided by that pack.
  • the well completion arrangement may comprise a well completion tubular or the like, having a plurality of inflow ports defined therethrough.
  • the effective inflow area of the well completion arrangement may be based on the number and size of the inflow ports.
  • the number and/or size of inflow ports may be based on the diameter of the well completion tubular, and/or the wellbore. For example, the greater the diameter, the greater the effective inflow area designed.
  • the well may comprise a plurality of well completion arrangements, which may be axially aligned and connected lengthwise.
  • the well may comprise a first well completion arrangement having a first effective inflow area and a second well completion arrangement having a second effective inflow area.
  • the second effective inflow area may be different from the first effective inflow area.
  • the multiple well completion arrangements may be provided such that fluid is permitted to flow along the multiple well completion arrangements in an annulus provided between the wellbore and surrounding formation.
  • Such completion arrangements may have an effective inflow area usable with the well described. Such completion arrangements may be specifically confirmed to optimise well performance (e.g. provide a particular PI).
  • the method may comprise:
  • the method may comprise providing a computational model of a well have a section of wellbore and surrounding formation, and calculating fluid production/injection between the surrounding formation to the wellbore for a particular length of well.
  • the method then may comprise varying the length of the well, and determining an optimal well length based on calculated fluid production/injection, or at least confirming that further well extensions would not improve performance, for example.
  • the method may comprise determining a profile for different lengths of well, for example.
  • a computer program product or computer file configured to at least partially (or fully) implement the apparatus and methods as described above.
  • a carrier medium e.g. non-transient carrier
  • the program or file may be non-transitory.
  • processing apparatus when programmed with the computer program product described.
  • the invention includes one or more corresponding aspects, embodiments or features in isolation or in various combinations whether or not specifically stated (including claimed) in that combination or in isolation.
  • features associated with particular recited embodiments relating to apparatus may be equally appropriate as features of embodiments relating specifically to methods of operation or use, and vice versa.
  • Figure 1 shows a simplified exemplary representation of a well generally identified by 10 extending through a subterranean formation 20 (e.g. a hydrocarbon-bearing formation).
  • a wellbore 30 e.g. comprising production tubing
  • the well 10 has been designed to have multiple well completion arrangements 100, which are positioned between the wellbore 30 and surrounding formation 20, as will be further described. It will be appreciated that such well completion arrangements 100 may be provided in sections that, when completed, are connected together along some or all of the length of the well 10.
  • While the well 10 of Figure 1 may be considered to show a deviated or horizontal well configuration, it will be appreciated that in other examples the apparatus and methods described herein may be used in vertical, or near-vertical, sections of a well 10, and indeed in mother bores and/or laterals, fishbones, etc., as may be expected. Further, the examples described herein may be used across a range of completion arrangements, including dual or multi-completions, as will be appreciated by a skilled reader. Further still, the examples described here have been given with reference to oil and gas production, but of course in other examples, the apparatus and methods may be used with other fluids being produced and/or injected. A skilled reader will readily be able to implement those various alternative embodiments accordingly.
  • well completion arrangements 100 are selected based on desired well performance and expected conditions at the formation 20. Therefore, where the formation 20 may be predominantly sandstone, or the like, screens (e.g. standalone screens, "SAS") may be installed in order to filter, and so mitigate the risk of, sands being produced in the event of fines being liberated at the formation.
  • screens e.g. standalone screens, "SAS"
  • Other sand control methods include gravel packs, autopacks (e.g. where an annulus is filled with formation sand), or the like.
  • Sand, or the like, that is produced can of course be harmful to well infrastructure and processing equipment, and affect long term well performance.
  • methods are required in order to control sand production, then there is a desire to minimise any restriction to flow from the formation 20 to the wellbore 30.
  • sand control may be necessary, it nevertheless is understood that the minimum restriction to flow, while meeting sand control requirements, would be preferable. In doing so, the performance of the well can be maximised, and the restriction - although necessary for sand control - affects as little as possible the overall well performance.
  • Simplified representations of standalone screens 100a used for sand control are shown in Figure 1 , by way of an example. Again, in other examples, dual or multi-completions may equally be used, depending on circumstance.
  • a well 10 can be designed such that well completion arrangements 100 may be used that comprise a plurality of inflow control devices or valves (ICDs and/or ICVs), which operate to control and restrict fluid being produced from the surrounding formation 20.
  • ICDs and/or ICVs inflow control devices or valves
  • Such well completion arrangements 100 comprising ICDs can be set at surface for a particular pressure drop across the devices at the time of running the well completion arrangement 100, or indeed can act autonomously so as to be open or closed when certain conditions are observed.
  • Well completion arrangements 100 having ICVs can also be controllable, e.g. from surface, in the event of an observed production of unwanted fluids, or to control fluid conditions within the wellbore, i.e. choke inflow at certain sections of the well.
  • the function of such ICD/ICV arrangements is generally to control and restrict the flow of unwanted fluid into the wellbore 30.
  • Figure 1 shows a simplified example of such well completion arrangements 100b, which would comprise a plurality of ICDs/ICVs (not shown for ease).
  • packers 110 or the like may be required in order to isolate the annulus provided between the formation 20 and the well completion arrangements 100b from that of axially adjacent annulus (i.e. and so provide zonal control).
  • PI productivity index
  • a typical process for a competent well engineer when designing such a well 10 includes initially considering the well objectives, such as productivity index, drainage requirements, fluids being produced, likely operations performed (e.g. acid injection, fracturing, etc.). This provides some constraints on the type of infrastructure that may be used in the well 10.
  • the options for well completion arrangements can be considered. These may include, for example, cased or perforated arrangements, open hole arrangements, or arrangements used from sand control, e.g. screens and/or gravel packs.
  • the specific type of well completion arrangements 100 that may be used can be down-selected based on the desired well objectives.
  • a simplified analysis or 1D nodal analysis (e.g. using Darcy laws) is then implemented, based on the formation data available in order to determine inflow potential at the wellbore 30.
  • the various sections of well completion arrangement 100 e.g. 100a, 100b
  • filter arrangements e.g. filter meshes, wires, screens, or the like
  • required valve arrangements e.g. packer positioning and type (e.g. swellables), etc., as may be required.
  • An approximation of actual "real world” well performance can then be provided by making analytical adjustments and offsets to the modelled well performance based on, for example, expected skin factor (e.g. an approximation of the "real world” damage that may limit the ability for the formation 20 to produce fluids - such damage to the formation 20 having taken place during drilling, completing, etc.).
  • expected skin factor e.g. an approximation of the "real world” damage that may limit the ability for the formation 20 to produce fluids - such damage to
  • FIG. 2 A simplified approximation of the well performance for a given well completion arrangement 100a, 100b (or indeed section of well 10 having multiple well completion arrangements 100) is shown by the solid-line profile 200 in Figure 2 .
  • well performance e.g. PI
  • FIG. 2 well performance (e.g. PI) is shown on the vertical y-axis, while overall restriction to flow from the formation 20 to the wellbore 30 through well completion arrangements 100 is shown on the horizontal x-axis.
  • the overall restriction to flow (or pressure drop) provided by well completion arrangements 100a, 100b may be approximated by an "effective inflow area". That is to say that the well completion arrangement 100a, 100b may be considered to define fluid paths (e.g. a plurality of fluid paths) between the surrounding formation 20 and the wellbore 30, and that those cumulative fluid paths provide an overall effective inflow area, or otherwise permeability, from the surrounding formation 20 to the wellbore 30. It will be appreciated that an effective inflow area may be approximated for various different types of well completion arrangements (e.g. from ICD/ICV completions to gravel packs, standalone screens, hydraulically enhanced sand screens, or the like).
  • the effective inflow area may be considered to be an aggregate of the collective inflow areas of ports or nozzles, or the like, at the completion. Those ports/nozzles may be uniform in size such that increasing number of ports/nozzles increases the effective inflow area.
  • the expected well performance remains low when using restricted completion including ICDs/ICVs. This is generally considered to be an acceptable trade off.
  • completion 100 may restrict the immediate maximum well performance, but on the other hand it does permit control of fluids.
  • the effective inflow area increases (i.e. along the x-axis) the well performance improves until essentially plateauing at a maximum well performance. It is expected that open hole arrangements, and to some extent very open sand screens, operate at this well performance. Therefore, conventional wisdom dictates that, where possible, the restriction to flow from the formation 20 to the wellbore 30 should be as minimal as possible so as not to unduly affect well performance.
  • Figure 2 shows a further example of a profile 300 of well performance (shown in broken lines) as predicted and observed by the inventors.
  • the expected well performance remains low when using restricted completion including ICDs/ICVs, as before.
  • the effective inflow area continues to increase, beyond that used in typical ICD/ICV completions 100b, the well performance potentially improves beyond that expected by the "standard" profile 200.
  • a point of inflection is reached (i.e. a maxima 310), after which further effective inflow area has the unexpected effect of reducing well performance.
  • the profile 300 shown in Figure 2 provides an exemplary approximation of well performance and effective inflow area when negative effects of the interaction of fluid flow into the wellbore 30 are taken into account.
  • the design of such a well 10 may initially include the development of a computational model 410.
  • the model of the well 10 may comprise the section of wellbore 30, surrounding formation 20, and a well completion arrangement 100 positioned between the wellbore 30 and surrounding formation 20.
  • the well completion arrangement 100 can define fluid paths between the surrounding formation 20 and the wellbore 30, whether that be in the form of inflow areas defined in well completion tubulars, and/or defined by the flow paths in gravel packs, autopacks, or the like.
  • the fluid paths can be considered to provide an effective inflow area (e.g. permeability) from the surrounding formation 20 to the wellbore 30.
  • the model may be a partial section model, a 2D model, or indeed a 3D representation of a section of the well 10.
  • the model may be implemented using computational fluid dynamics. In other cases, alternative numerical analysis may be used. In some cases, however, the model may approximate components, such as the well completion arrangement 100, by associating a viscous resistance with those components, as described by the inventor's UK and US granted Patents GB2515411 , GB2474275 and US8849637 . As such, a single fluid CFD model that is able to model fluid flow from formation 20 through to wellbore 30 may be implemented.
  • the specific geometry of the components in the well may be modelled together with the overall geometry of the well.
  • the specific geometry e.g. size, inflow area, orientation, etc.
  • the model of the well may comprise both the geometry of the well at a relative macro scale, as well as the geometry of the well components at a relative micro scale.
  • the well completion arrangements 100 can be selected having particular effective inflow areas for initial calculation of well performance.
  • the initial selection 420 of the effective inflow area may be provided by inflow ports of known sizes, e.g. commercially available ICD/nozzle arrangements (i.e. devices having known diameters given that these can be used with ease in any finally-designed completion 100).
  • the number of inflow ports or the like may be selected, which may be defined in a number of different configurations, such as through a base pipe or completion tubular, provided by tortuous paths, axial tubes or nozzles, in a housing surrounding a base pipe, or the like, in a known manner.
  • the fluid being produced from the surrounding formation 20, through the well completion arrangement 100, to the wellbore 30 can be calculated 430 for a given effective inflow area. This may permit calculation of well performance for that given effective inflow area, and the initial compilation of the profile 300 shown in Figure 3 for those particular well conditions.
  • the effective inflow area of the well completion arrangements 100 can be varied 420, and the fluid being produced recalculated. It will be appreciated that a range of effective inflow areas may be used in order to develop the profile 300 of well performance. From that profile 300 of well performance, an optimal well design may be determined 460 having a particular effective inflow area (or range of possible effective inflow areas) based on the determined profile 300.
  • both the size and number of inflow ports may be varied in order to vary the effective inflow area.
  • the effective permeability e.g. when using gravel packs, autopacks, etc.
  • the effective inflow area may be varied in order to vary the effective inflow area.
  • a maxima is shown in a curved or otherwise parabolic profile 300 of well performance across the range of effective inflow areas of the well completion arrangement 100.
  • further points or inflection or variances in profile 300 are observed across the range of effective inflow areas. Nonetheless, an optimal solution may be obtained, which may likely be around the point of inflection of a section of the profile 300.
  • the well design may be restricted such that, due to external commercial restrictions or constraints, only a selection of particular well completion arrangements 100 are available, e.g. having a range of predefined inflow ports of particular number/sizes.
  • the optimised well design may include the most effective well completion arrangement 100, based on the modelled analysis.
  • Such well completion arrangements 100 may have an effective inflow area tending towards the maxima (e.g. as close as possible based on the completion 100 available), or may be most cost effective based on the potential performance gains versa difference in well completion costs.
  • the determined effective inflow area may be between a lower inflow area threshold 320, below which the inflow area corresponds to that of well completion arrangements comprising inflow control devices/valves for control of fluids, and a upper inflow area threshold 330, above which the inflow area corresponds to that of well completion arrangements 100 configured as standalone screens.
  • the well design may simply specify that the well completion arrangements 100 are configured to sit within that range.
  • an optimal well design may be determined having a well completion arrangement of a particular effective inflow area based on a profile of well performance, where the profile of well performance has been determined from expected fluid production based on a range of effective inflow areas.
  • the "real life" well 10 may then be completing by positioning the well completion arrangement 100 between wellbore and surrounding formation and, where necessary, modifying the effective inflow area (e.g. using ICVs).
  • the designed well completion arrangement may be configured for controllable inflow, e.g. comprising a plurality of inflow control valves, or the like, which may be operable to provide a variable effective inflow area.
  • the well completion design may specify the expected optimal effective inflow area together with a range of effective inflow areas such that, when deployed, the effective area inflow of the well completion arrangement can be controlled in order to fine-tune performance (e.g. in the event that optimal performance is observed to be at a slightly different effective inflow area than that calculated).
  • the methodology outlined in Figure 3 may be implemented without the need for a computer model, as such.
  • an approximation of the optimal inflow area may be postulated, and well completion arrangements 100 deployed having the capability to vary their effective inflow areas.
  • those well completion arrangements may be modified so as to optimise performance (e.g. determining the profile 300 of well performance, experimentally).
  • Figure 4 shows an example of a section of well 15 comprising a section of wellbore 35, well completion arrangement 150 and surrounding formation 25, wherein the well 15 is configured such that fluids are produced from the surrounding formation 25, through the well completion arrangement 150, to the wellbore 35.
  • the well completion arrangement 150 defines fluid paths 152, 155 between the surrounding formation 25 and the wellbore 35, those fluid paths 152, 155 providing an effective inflow area from the surrounding formation 25 to the wellbore 15, as above.
  • the effective inflow areas 152, 155 are provided so as to optimise well performance.
  • two well completion arrangements 150a, 150b are axially aligned and connected lengthwise.
  • a first well completion arrangement 150a has been provided with a first effective inflow area
  • a second well completion arrangement 150b has been provided with a second effective inflow area, the second effective inflow area being different from the first effective inflow area.
  • the number and/or size of inflow ports is different between first and second well completion arrangements 150a, 150b.
  • fluid may be permitted to flow along the multiple well completion arrangements in an annulus 170 provided between the modelled wellbore and surrounding formation. In other words, no packers are required as the effective inflow areas are not intended to be used for zonal isolation.
  • the method may comprise providing a computational model of a well have a section of wellbore and surrounding formation, and calculating fluid production from the surrounding formation to the wellbore for a particular length of well. The method then may comprise determining an optimal well length based on calculated fluid production, or at least confirming that further well extensions would not improve performance, for example.

Landscapes

  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Consolidation Of Soil By Introduction Of Solidifying Substances Into Soil (AREA)

Claims (15)

  1. Procédé de conception de puits optimale, le procédé comprenant :
    la fourniture d'un modèle de calcul (410) d'un puits (10), le modèle de calcul (410) comprenant une section de puits de forage (30), une formation environnante (20), et un agencement de complétion de puits (100, 100A, 100B) positionné entre le puits de forage (30) et la formation environnante (20), l'agencement de complétion de puits (100, 100A, 100B) définissant des chemins de fluide entre la formation environnante (20) et le puits de forage (30), dans lequel les chemins de fluide fournissent une zone d'entrée de flux effective de la formation environnante (20) au puits de forage (30) ; et ensuite
    a. le calcul de la production de fluide de la formation environnante (20), à travers l'agencement de complétion de puits (100, 100A, 100B, 150A, 150B), jusqu'au puits de forage (30) ; et
    b. la modification de la zone d'entrée de flux efficace de l'agencement de complétion de puits (100, 100A, 100B, 150A, 150B) ; et
    la répétition des étapes a. et b. de façon à déterminer un profil de performances de puits pour ce modèle de calcul (410) du puits (10) sur la base d'une gamme de zones d'entrée de flux effectives de l'agencement de complétion de puits (100, 100A, 100B, 150A, 150B) ; et
    la détermination d'une conception de puits optimale présentant une zone d'entrée de flux effective particulière sur la base du profil déterminé ; et dans lequel
    le modèle de calcul (410) comprend une pluralité d'agencements de complétion de puits (100, 100A, 100B, 150A, 150B), alignés de manière axiale et connectés dans le sens de la longueur ;
    la pluralité d'agencements de complétion de puits (100, 100A, 100B, 150A, 150B) comprenant au moins un premier agencement de complétion de puits présentant une première zone d'entrée de flux effective et un second agencement de complétion de puits présentant une seconde zone d'entrée de flux, la seconde zone d'entrée de flux effective étant différente de la première zone d'entrée de flux effective ; et
    la zone d'entrée de flux effective de chaque achèvement de puits (100, 100A, 100B, 150A, 150B) est variée de manière individuelle pour déterminer la conception de puits optimale.
  2. Procédé selon la revendication 1, dans lequel les étapes a. et b. sont répétées de façon à fournir un profil de performances du puits à travers la gamme de zones d'entrée de flux effectives de l'agencement de complétion de puits, et dans lequel la zone d'entrée de flux effectives de la conception de puits optimale concerne une région associée à un point d'inflexion du profil.
  3. Procédé selon la revendication 1 ou 2, dans lequel la zone d'entrée de flux effective de la conception de puits optimale fournit la production de fluide maximale pour ce puits de forage modélisé et la formation environnante.
  4. Procédé selon la revendication 3, dans lequel la zone d'entrée de flux effective déterminée se situe entre un seuil de zone d'entrée de flux inférieur, sous lequel la zone d'entrée de flux correspond à celle d'agencements de complétion de puits comprenant des dispositifs de contrôle d'entrée de flux pour contrôler des fluides, et un seuil de zone d'entrée de flux supérieur, au-dessus duquel la zone d'entrée de flux correspond à celle d'agencements de complétion de puits configurés comme des tamis autonomes.
  5. Procédé selon l'une quelconque des revendications 1 à 4, dans lequel le profil de performances du puits est fourni en termes d'indice de productivité.
  6. Procédé selon l'une quelconque des revendications 1 à 5, dans lequel l'agencement de complétion de puits modélisé comprend un massif filtrant, modélisé pour avoir une zone d'entrée de flux effective fournie par ce massif filtrant.
  7. Procédé selon l'une quelconque des revendications 1 à 5, dans lequel l'agencement de complétion de puits modélisé comprend une pluralité d'orifices d'entrée de flux, définis à travers un tubulaire de complétion de puits.
  8. Procédé selon la revendication 7, dans lequel :
    la zone d'entrée de flux effectif est basée sur le nombre et la taille des orifices d'entrée de flux ; et/ou
    au moins une zone d'entrée de flux effective utilisée dans la plage de zones d'entrée de flux effectives est sélectionnée sur la base du diamètre du tubulaire de complétion de puits, et ou du diamètre de puits de forage.
  9. Procédé selon l'une quelconque des revendications 1 à 8, dans lequel la plage de zones d'entrée de flux effectives sont sélectionnées sur la base d'un ou plusieurs de : un taux de production de fluide souhaité, une longueur de puits, ou des propriétés de formation.
  10. Procédé selon la revendication 8 ou toute revendication qui en dépend, dans lequel le nombre d'orifices d'entrée de flux est différent entre le premier et le second agencement de complétion de puits.
  11. Procédé selon l'une quelconque des revendications précédentes, dans lequel le modèle de calcul comprenant plusieurs agencements de complétion de puits est modélisé de sorte qu'un fluide soit autorisé à s'écouler le long des plusieurs agencements de complétion de puits dans un circuit ménagé entre le puits de forage modélisé et la formation environnante.
  12. Procédé selon l'une quelconque des revendications précédentes, dans lequel le procédé comprend l'association d'une résistance visqueuse particulière à l'agencement de complétion de puits, et d'une résistance visqueuse particulière à la formation environnante pour calculer une production de fluide à partir de la formation environnante, à travers l'agencement de complétion de puits, jusqu'au puits de forage.
  13. Procédé selon l'une quelconque des revendications 1 à 11, dans lequel le modèle de calcul du puits est un modèle de dynamique de fluide numérique (CFD).
  14. Procédé de construction de puits optimale comprenant :
    la détermination d'une conception de puits optimale présentant un agencement de complétion de puits d'une zone d'entrée de flux effective particulière sur la base d'un profil de performances de puits en utilisant le procédé selon l'une quelconque des revendications 1 à 11 ; et
    l'achèvement d'une section de puits en positionnant l'agencement de complétion de puits entre le puits de forage et la formation environnante.
  15. Produit de programme informatique ou fichier informatique comprenant des instructions qui, lorsque le programme ou le fichier est exécuté par un ordinateur, amène l'ordinateur à réaliser le procédé selon l'une quelconque des revendications 1 à 11.
EP18797061.1A 2017-10-27 2018-10-26 Conception de puits et structure de puits associèe Active EP3701119B8 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
GBGB1717738.7A GB201717738D0 (en) 2017-10-27 2017-10-27 Well design and associated well structures
PCT/GB2018/053110 WO2019081948A1 (fr) 2017-10-27 2018-10-26 Conception de puits et structures de puits associées

Publications (3)

Publication Number Publication Date
EP3701119A1 EP3701119A1 (fr) 2020-09-02
EP3701119B1 true EP3701119B1 (fr) 2022-06-01
EP3701119B8 EP3701119B8 (fr) 2022-07-13

Family

ID=60580263

Family Applications (1)

Application Number Title Priority Date Filing Date
EP18797061.1A Active EP3701119B8 (fr) 2017-10-27 2018-10-26 Conception de puits et structure de puits associèe

Country Status (3)

Country Link
EP (1) EP3701119B8 (fr)
GB (1) GB201717738D0 (fr)
WO (1) WO2019081948A1 (fr)

Families Citing this family (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US11574083B2 (en) 2020-05-11 2023-02-07 Saudi Arabian Oil Company Methods and systems for selecting inflow control device design simulations based on case selection factor determinations

Family Cites Families (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB2515411B (en) * 2009-10-09 2015-06-10 Senergy Holdings Ltd Well simulation
DE112013007286T5 (de) * 2013-08-01 2016-04-14 Landmark Graphics Corporation Algorithmus zur optimalen ZSV-Konfiguration mithilfe eines gekoppelten Bohrloch-Lagerstätten-Modells
WO2015019112A2 (fr) * 2013-08-08 2015-02-12 Senergy Holdings Limited Procédés et appareil pour une productivité de puits

Also Published As

Publication number Publication date
EP3701119B8 (fr) 2022-07-13
EP3701119A1 (fr) 2020-09-02
WO2019081948A1 (fr) 2019-05-02
GB201717738D0 (en) 2017-12-13

Similar Documents

Publication Publication Date Title
EP2432968B1 (fr) Appareil et procédé de modélisation de conceptions de puits et de performance de puits
AU2006333562B2 (en) Profile control apparatus and method for production and injection wells
US10815766B2 (en) Vertical drilling and fracturing methodology
US20120278053A1 (en) Method of Providing Flow Control Devices for a Production Wellbore
US10891407B2 (en) System and method for automated-inflow control device design
Luo et al. A new semi-analytical model for predicting the performance of horizontal wells completed by inflow control devices in bottom-water reservoirs
US20110067871A1 (en) Methods For Regulating Flow In Multi-Zone Intervals
US11306572B2 (en) Hydraulic fracturing modelling and control
WO2017223483A1 (fr) Procédé de sélection de tailles d'étrangleur, de paramètres de pompage artificiel, de tailles de tuyaux et d'installations de surface soumis à des contraintes de système de production pour puits de pétrole et de gaz
WO2019241458A1 (fr) Définition d'un programme de complétion pour un puits de pétrole et de gaz
EP3701119B1 (fr) Conception de puits et structure de puits associèe
Alsyed et al. Testing methodology for smart wells completion toward attaining optimal production rate setting for maximum hydrocarbon recovery
CA2990838C (fr) Systeme et procede pour reduire la production de fluides dans un puits
Liu et al. A Multi-Factor Approach to Optimize Horizontal Shale Wells Flowback and Production Operation
EP2022935A1 (fr) Procédé de drainage de réservoirs à couches multiples
Mohammadpourmarzbali et al. Improved waterflood performance by employing permanent down-dole control devices: Iran case study
Carpenter Optimized design of autonomous inflow-control devices for gas and water coning
EP3085885A1 (fr) Procédé, appareil et programme informatique permettant de déterminer la production à partir de chaque complétion de puits de complétion double de gaz levé
Carpenter Autonomous Inflow-Control Devices Boost Production While Managing Sand
Wilson Drilling and Completion Technique Selection for Coalbed Methane Wells
Wang et al. Physical Modeling of Production Potential for Expandable Screen Well Compilation
Carpenter One-Trip Multizone Sand-Control-Completion System in the Gulf of Mexico Lower Tertiary
Carpenter Production Performance in the In-Fill Development of Unconventional Resources
Wilson Coupling reservoir and well-completion simulators for intelligent multilateral wells
Galimzyanov et al. Advances in Modeling of Passive Inflow Control Devices Help Optimizing Horizontal Well Completions

Legal Events

Date Code Title Description
STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: UNKNOWN

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: THE INTERNATIONAL PUBLICATION HAS BEEN MADE

PUAI Public reference made under article 153(3) epc to a published international application that has entered the european phase

Free format text: ORIGINAL CODE: 0009012

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: REQUEST FOR EXAMINATION WAS MADE

17P Request for examination filed

Effective date: 20200521

AK Designated contracting states

Kind code of ref document: A1

Designated state(s): AL AT BE BG CH CY CZ DE DK EE ES FI FR GB GR HR HU IE IS IT LI LT LU LV MC MK MT NL NO PL PT RO RS SE SI SK SM TR

AX Request for extension of the european patent

Extension state: BA ME

DAV Request for validation of the european patent (deleted)
DAX Request for extension of the european patent (deleted)
GRAP Despatch of communication of intention to grant a patent

Free format text: ORIGINAL CODE: EPIDOSNIGR1

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: GRANT OF PATENT IS INTENDED

INTG Intention to grant announced

Effective date: 20211007

GRAS Grant fee paid

Free format text: ORIGINAL CODE: EPIDOSNIGR3

GRAA (expected) grant

Free format text: ORIGINAL CODE: 0009210

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: THE PATENT HAS BEEN GRANTED

AK Designated contracting states

Kind code of ref document: B1

Designated state(s): AL AT BE BG CH CY CZ DE DK EE ES FI FR GB GR HR HU IE IS IT LI LT LU LV MC MK MT NL NO PL PT RO RS SE SI SK SM TR

REG Reference to a national code

Ref country code: GB

Ref legal event code: FG4D

REG Reference to a national code

Ref country code: DE

Ref legal event code: R081

Ref document number: 602018036288

Country of ref document: DE

Owner name: LLOYD'S REGISTER DIGITAL PRODUCTS LIMITED, KIN, GB

Free format text: FORMER OWNER: LLOYD'S REGISTER GROUP LIMITED, KINGSWELLS, ABERDEEN, GB

REG Reference to a national code

Ref country code: AT

Ref legal event code: REF

Ref document number: 1495480

Country of ref document: AT

Kind code of ref document: T

Effective date: 20220615

Ref country code: CH

Ref legal event code: PK

Free format text: BERICHTIGUNG B8

Ref country code: CH

Ref legal event code: EP

Ref country code: DE

Ref legal event code: R096

Ref document number: 602018036288

Country of ref document: DE

Ref country code: GB

Ref legal event code: 732E

Free format text: REGISTERED BETWEEN 20220519 AND 20220525

REG Reference to a national code

Ref country code: IE

Ref legal event code: FG4D

RAP2 Party data changed (patent owner data changed or rights of a patent transferred)

Owner name: LLOYD'S REGISTER DIGITAL PRODUCTS LIMITED

REG Reference to a national code

Ref country code: LT

Ref legal event code: MG9D

REG Reference to a national code

Ref country code: NL

Ref legal event code: MP

Effective date: 20220601

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: SE

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20220601

Ref country code: NO

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20220901

Ref country code: LT

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20220601

Ref country code: HR

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20220601

Ref country code: GR

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20220902

Ref country code: FI

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20220601

Ref country code: ES

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20220601

Ref country code: BG

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20220901

REG Reference to a national code

Ref country code: AT

Ref legal event code: MK05

Ref document number: 1495480

Country of ref document: AT

Kind code of ref document: T

Effective date: 20220601

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: RS

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20220601

Ref country code: PL

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20220601

Ref country code: LV

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20220601

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: NL

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20220601

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: SM

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20220601

Ref country code: SK

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20220601

Ref country code: RO

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20220601

Ref country code: PT

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20221003

Ref country code: EE

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20220601

Ref country code: CZ

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20220601

Ref country code: AT

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20220601

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: IS

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20221001

REG Reference to a national code

Ref country code: DE

Ref legal event code: R097

Ref document number: 602018036288

Country of ref document: DE

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: AL

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20220601

PLBE No opposition filed within time limit

Free format text: ORIGINAL CODE: 0009261

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: NO OPPOSITION FILED WITHIN TIME LIMIT

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: DK

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20220601

REG Reference to a national code

Ref country code: DE

Ref legal event code: R119

Ref document number: 602018036288

Country of ref document: DE

26N No opposition filed

Effective date: 20230302

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: SI

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20220601

Ref country code: MC

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20220601

REG Reference to a national code

Ref country code: CH

Ref legal event code: PL

REG Reference to a national code

Ref country code: BE

Ref legal event code: MM

Effective date: 20221031

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: LU

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20221026

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: LI

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20221031

Ref country code: FR

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20221031

Ref country code: DE

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20230503

Ref country code: CH

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20221031

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: BE

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20221031

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: IE

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20221026

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: IT

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20220601

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: CY

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20220601

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: MK

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20220601

Ref country code: HU

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT; INVALID AB INITIO

Effective date: 20181026

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: MT

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20220601

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: GB

Payment date: 20240906

Year of fee payment: 7