CA3014272C - Modular well pad systems and methods - Google Patents
Modular well pad systems and methods Download PDFInfo
- Publication number
- CA3014272C CA3014272C CA3014272A CA3014272A CA3014272C CA 3014272 C CA3014272 C CA 3014272C CA 3014272 A CA3014272 A CA 3014272A CA 3014272 A CA3014272 A CA 3014272A CA 3014272 C CA3014272 C CA 3014272C
- Authority
- CA
- Canada
- Prior art keywords
- well
- module
- pair
- pair module
- another
- 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
Links
- 238000000034 method Methods 0.000 title description 15
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 claims description 52
- 238000004519 manufacturing process Methods 0.000 claims description 48
- 239000007789 gas Substances 0.000 claims description 30
- 239000000839 emulsion Substances 0.000 claims description 27
- 238000002347 injection Methods 0.000 claims description 27
- 239000007924 injection Substances 0.000 claims description 27
- 239000003345 natural gas Substances 0.000 claims description 26
- 239000012530 fluid Substances 0.000 claims description 25
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 12
- 238000012545 processing Methods 0.000 claims description 4
- 239000000243 solution Substances 0.000 claims description 3
- 230000005611 electricity Effects 0.000 claims 1
- 239000012263 liquid product Substances 0.000 claims 1
- 238000013461 design Methods 0.000 description 13
- 238000010796 Steam-assisted gravity drainage Methods 0.000 description 10
- 239000012071 phase Substances 0.000 description 6
- 230000015572 biosynthetic process Effects 0.000 description 4
- 239000007788 liquid Substances 0.000 description 3
- 239000010426 asphalt Substances 0.000 description 2
- 238000010276 construction Methods 0.000 description 2
- 238000005259 measurement Methods 0.000 description 2
- 230000001105 regulatory effect Effects 0.000 description 2
- 238000000926 separation method Methods 0.000 description 2
- 241000191291 Abies alba Species 0.000 description 1
- 238000010793 Steam injection (oil industry) Methods 0.000 description 1
- 238000009833 condensation Methods 0.000 description 1
- 230000005494 condensation Effects 0.000 description 1
- 230000001276 controlling effect Effects 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 238000000605 extraction Methods 0.000 description 1
- 238000010438 heat treatment Methods 0.000 description 1
- 238000009434 installation Methods 0.000 description 1
- 239000007791 liquid phase Substances 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 238000005086 pumping Methods 0.000 description 1
- 239000011369 resultant mixture Substances 0.000 description 1
- 239000004576 sand Substances 0.000 description 1
- 239000002689 soil Substances 0.000 description 1
- 238000012360 testing method Methods 0.000 description 1
- 238000012876 topography Methods 0.000 description 1
- 238000012546 transfer Methods 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
- E21B43/30—Specific pattern of wells, e.g. optimizing the spacing of wells
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/24—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
- E21B43/2406—Steam assisted gravity drainage [SAGD]
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
- E21B43/121—Lifting well fluids
- E21B43/128—Adaptation of pump systems with down-hole electric drives
Abstract
A modular well pad system, which includes a first inlet module, a second inlet module, a 1 well-pair module and a 2 well-pair module. The first and second inlet modules, one or more 1 well-pair modules and one or more 2 well-pair modules may be configured to build an interconnected well pad system for accommodating one to twelve well-pairs wherein standardized connections enable the 1 well-pair module and the 2 well-pair module to be coupled together, to the second inlet module, another 1 well-pair module and/or another 2 well-pair module.
Description
MODULAR WELL PAD SYSTEMS AND METHODS
FIELD OF THE DISCLOSURE
FIELD OF THE DISCLOSURE
[0002] The present disclosure generally relates to modular well pad systems and methods.
More particularly, the present disclosure relates to a modular well pad system, which includes a first inlet module, a second inlet module, a 1 well-pair module and a 2 well-pair module. The first and second inlet modules, one or more 1 well-pair modules and one or more 2 well-pair modules may be configured to build an interconnected well pad system for accommodating one to twelve well-pairs wherein standardized connections enable the 1 well-pair module and the 2 well-pair module to be coupled together, to the second inlet module, another 1 well-pair module and/or another 2 well-pair module.
BACKGROUND
More particularly, the present disclosure relates to a modular well pad system, which includes a first inlet module, a second inlet module, a 1 well-pair module and a 2 well-pair module. The first and second inlet modules, one or more 1 well-pair modules and one or more 2 well-pair modules may be configured to build an interconnected well pad system for accommodating one to twelve well-pairs wherein standardized connections enable the 1 well-pair module and the 2 well-pair module to be coupled together, to the second inlet module, another 1 well-pair module and/or another 2 well-pair module.
BACKGROUND
[0003] Steam Assisted Gravity Drainage (SAGD) is a methodology of oil extraction where steam is injected into the underground oil reservoir through an injection well and bituminous product is collected though a production well. The steam is injected downhole to melt bitumen trapped within a sand layer, typically anywhere from 200 to 500 meters below grade. The resultant mixture of bitumen and water (hereinafter referred to as a production emulsion) flows up through the production well, potentially with some free gas, where a well pad and surface facilities handle the transfer of the production emulsion to a central processing facility (CPF). Because the production emulsion is a multiphase product, the liquid and gases are separated and sent to the CPF. Conventional SAGD well pads thus, require the use of separator vessels.
[0004] Conventional SAGD well pads are often constructed in a way that allows for much of the construction and fabrication work to be performed offsite, in a more controlled environment, and then assembled on-site. Each well pad thus, may include multiple modules that can be shipped by highway on a flatbed trailer of a transport truck and then lowered or lifted into place for assembly on-site. Such modules, however, still lack the requisite standardization necessary to permit simple interconnectivity between the modules regardless of the module type, well pad location and design parameters. Moreover, the lack of simple intercormectivity also renders such modules significantly inflexible for expansion. As a result, conventional SAGD
well pads remain highly customized and therefore, costly to construct.
BRIEF DESCRIPTION OF THE DRAWINGS
well pads remain highly customized and therefore, costly to construct.
BRIEF DESCRIPTION OF THE DRAWINGS
[0005] The present disclosure is described with reference to the accompanying drawings, in which like elements are referenced with like reference numbers, and in which:
[0006] FIG. 1 is a site plan illustrating one embodiment of a modular well-pad system comprising a first inlet module, a second inlet module, a 1 well-pair module and two 2 well-pair modules for accommodating 5 well-pairs.
[0007] FIG. 2 is a schematic view of the first inlet module in FIG. 1 illustrating standardized connections to the first inlet module.
[0008] FIG. 3 is a schematic view of the second inlet module in FIG. 1 illustrating standardized connections to the second inlet module.
[0009] FIG. 4 is a schematic view of the 1 well-pair module in FIG. 1 illustrating standardized connections to the 1 well-pair module.
[0010] FIG. 5 is a schematic view of the 2 well-pair module in FIG. 1 illustrating standardized connections to the 2 well-pair module.
DETAILED DESCRIPTION OF THE ILLUSTRATIVE EMBODIMENTS
DETAILED DESCRIPTION OF THE ILLUSTRATIVE EMBODIMENTS
[0011] The subject matter of the present disclosure is described with specificity, however, the description itself is not intended to limit the scope of the disclosure. The subject matter thus, might also be embodied in other ways, to include different structures, steps and/or combinations similar to and/or fewer than those described herein, in conjunction with other present or future technologies. Moreover, although the term "step" may be used herein to describe different elements of methods employed, the term should not be interpreted as implying any particular order among or between various steps herein disclosed unless otherwise expressly limited by the description to a particular order. Other features and advantages of the disclosed embodiments will be or will become apparent to one of ordinary skill in the art upon examination of the following figures and detailed description. It is intended that all such additional features and advantages be included within the scope of the disclosed embodiments.
Further, the illustrated figures are only exemplary and are not intended to assert or imply any limitation with regard to the environment, architecture, design, or process in which different embodiments may be implemented.
Further, the illustrated figures are only exemplary and are not intended to assert or imply any limitation with regard to the environment, architecture, design, or process in which different embodiments may be implemented.
[0012] The pressure profile for a well-pad cannot be standardized because the location of each well pad in relation to the CPF is unique to each project. Similarly, the topography along the right of way is also unique to each project. Due to these factors, the selection of some well-pad design parameters (e.g. single phase pipelines vs multi-phase pipeline;
separation on or off the well pad; pipeline size (internal diameter); and pumping configuration ¨
pumps in series, multi-phase pumps), based on costs, cannot be easily made using a standardized design. As used herein, the terms "pipeline" and "pipelines" may also be referred to as piping, line or lines.
separation on or off the well pad; pipeline size (internal diameter); and pumping configuration ¨
pumps in series, multi-phase pumps), based on costs, cannot be easily made using a standardized design. As used herein, the terms "pipeline" and "pipelines" may also be referred to as piping, line or lines.
[0013] Other parameters of the well pad design and its production (engineering, procurement, fabrication, installation and construction), however, may be standardized to achieve substantial production savings. The modular well pad described herein employs carefully controlled reservoir pressure and temperature conditions along with the use of submersible downhole pumps that produce a product with a single liquid phase, thereby eliminating the requirement for separator vessels and a costly gas pipeline back to the CPF.
The modular well pad and its production may thus, be standardized by (i) removing separators (group and test) from the design by raising the product pressure to above the bubble point using electric submersible pumps (ESPs); (ii) providing an option to connect to a multi-phase pump to boost the pressure further if need be to remain a single phase (liquid) for the product; and iii) providing an option to connect to a separation building if required to enable two single phase pipelines (1 gas, 1 liquid emulsion) for the product.
The modular well pad and its production may thus, be standardized by (i) removing separators (group and test) from the design by raising the product pressure to above the bubble point using electric submersible pumps (ESPs); (ii) providing an option to connect to a multi-phase pump to boost the pressure further if need be to remain a single phase (liquid) for the product; and iii) providing an option to connect to a separation building if required to enable two single phase pipelines (1 gas, 1 liquid emulsion) for the product.
[0014] Because the modular well-pad connections between modules are standardized, the modular well-pad allows for increased flexibility and repeatability without any additional engineering. Moreover, production costs for the modular well-pad are lowered because the modular well-pad is based on a design that: i) reduces the scope of a well-pad to the maximum possible extent without sacrificing life cycle cost; ii) reduces the scope of on-site field production 01 November 2017 01-11-2017 using modularization; iii) reduces materials; iv) provides options to enable the design to be customized and v) expands potential production locations by reducing the module size.
[0015] The modular well-pad thus overcomes one or more of the prior art disadvantages with a first inlet module, a second inlet module, a 1 well-pair module and a 2 well-pair module. The first and second inlet modules, one or more 1 well-pair modules and one or more 2 well-pair modules may be configured to build an interconnected well pad system for accommodating one to twelve well-pairs wherein standardized connections enable the 1 well-pair module and the 2 well-pair module to be coupled together, to the second inlet module, another 1 well-pair module and/or another 2 well-pair module.
[0016] In one embodiment the present disclosure includes a modular well-pad system, comprising: an inlet module comprising a plurality of service lines, wherein one or more of the plurality of service lines is connected at one side of the inlet module to a central processing facility and the plurality of service lines is connected at another end of the inlet module to a respective plurality of service lines at one end of another inlet module, the plurality of service lines connected at the one end of the another inlet module connectable at another end of the another inlet module to a respective plurality of service lines at one end of a 1 well-pair module and a respective plurality of service lines at one end of a 2 well-pair module; at least one of the 1 well-pair module and the 2 well-pair module, wherein the plurality of service lines at the one end of the 1 well-pair module are connectable at another end of the 1 well-pair module to a respective plurality of service lines at one end of amother 1 well-pair module and a respective plurality of service lines at one end of the 2 well-pair module and the plurality of service lines at the one end of the 2 well-pair module are connectable at another end of the 2 well-pair module to a respective plurality of service lines AMENDED SHEET
01 November 2017 01-11-2017 at one end of another 2 well-pair module and a respective plurality of service lines at the one end of the 1 well-pair module; and the 1 well-pair module connectable to one well pair and the 2 well-pair module connectable to two well pairs, wherein each well pair represents an injection well and a production well.
01 November 2017 01-11-2017 at one end of another 2 well-pair module and a respective plurality of service lines at the one end of the 1 well-pair module; and the 1 well-pair module connectable to one well pair and the 2 well-pair module connectable to two well pairs, wherein each well pair represents an injection well and a production well.
[0017] Referring now to FIG. 1, a site plan 100 illustrates one embodiment of a modular well-pad system comprising a first inlet module 102a, a second inlet module 102b, a 1 well-pair module 104 and two 2 well-pair modules 106 for accommodating five well-pairs 108-116. Each well pair represents one production well (p) and one steam injection well (i). The modular well-pad system may also include various support structures. A
natural gas heater 118 is used for heating the natural gas in order to avoid the formation of condensation in the natural gas entering the first inlet module 102a. An instrument air package (consisting of compressor, dryer and receiver) 120 is used for providing the instrument air entering the first inlet module 102a that controls the valves in each module.
An optional start-up package 122 may be used for providing start-up fluid entering the first inlet module 102a that supports the formation of a steam chamber below each injection well as part of the SAGD process. An electrical building 124 is used for transmitting power to i) each ESP below each production well; ii) each electrical heat tracing (EHT) panel for freeze protection on the piping in each module; and iii) general utilities (e.g. lighting) in each module. A stick built cable tray and pipe (not shown) connects the electrical AMENDED SHEET
building 124 to the first inlet module 102a. The electric building 124 also includes a pre-fabricated access platform and stairs (not shown). An ATCO transformer 126 is used for supplying power to the electrical building 124 and variable frequency drive (VFD) skids 128 are used for controlling the power to each ESP. A stock pile may be used for storing excess soil and a storm water pond may be used for collecting excess water runoff from the well-pad system.
natural gas heater 118 is used for heating the natural gas in order to avoid the formation of condensation in the natural gas entering the first inlet module 102a. An instrument air package (consisting of compressor, dryer and receiver) 120 is used for providing the instrument air entering the first inlet module 102a that controls the valves in each module.
An optional start-up package 122 may be used for providing start-up fluid entering the first inlet module 102a that supports the formation of a steam chamber below each injection well as part of the SAGD process. An electrical building 124 is used for transmitting power to i) each ESP below each production well; ii) each electrical heat tracing (EHT) panel for freeze protection on the piping in each module; and iii) general utilities (e.g. lighting) in each module. A stick built cable tray and pipe (not shown) connects the electrical AMENDED SHEET
building 124 to the first inlet module 102a. The electric building 124 also includes a pre-fabricated access platform and stairs (not shown). An ATCO transformer 126 is used for supplying power to the electrical building 124 and variable frequency drive (VFD) skids 128 are used for controlling the power to each ESP. A stock pile may be used for storing excess soil and a storm water pond may be used for collecting excess water runoff from the well-pad system.
[0018] The modular well-pad system is based on receiving a pre-drilled well-pad to rough grade with an installed power transformer 126. Each module is sized for international transport by sea, rail and/or road and designed to be lowered onto piles so that the on-site use of cranes is minimized. Because the modular well-pad system and its production is largely standardized, it is expandable from one well-pair up to a maximum of twelve well-pairs within a well-pad boundary 134 using I and 2 well-pair modules that can be assembled in any configuration necessary to achieve the required count. Module access is at grade, removing the requirement for a platform.
[0019] Referring now to FIG. 2, a schematic sectional view of the first inlet module 102a in FIG. 1 illustrates standardized connections to the first inlet module 102a.
The first inlet module 102a functions as the interface between the interconnecting pipelines to and from the CPF and interconnecting pipelines from other support structures. An emulsion line and a casing gas line are connected to one end and one side of the first inlet module 102a.
Emulsion and casing gas produced by each production well (p) in the well-pairs 108-116 (FIG. 1) enter one end of the first inlet module 102a from the second inlet module 102b and exit one side of the first inlet module 102a to the CPF. A steam line and a natural gas line are also connected to one end and one side of the first inlet module 102a. Steam and natural gas enter one side of the first inlet module 102a from the CPF and exit one end of the first inlet module 102a to the second inlet module 102b. An instrument air-line and a start-up fluid line are connected to one end and opposite sides of the first inlet module 102a. Instrument air and start -up fluid enter opposite sides of the first inlet module 102a from the instrument air package 120 and the start-up package 122, respectively, and exit one end of the first inlet module 102a to the second inlet module 102a. The instrument air entering the first inlet module 102a controls any valves in the first inlet module 102a such as the emergency shutdown valves for the critical steam, emulsion, natural gas, casing gas, and start-up fluid lines at the well pad limits. The first inlet module 102a also includes the required metering for process measurement of steam, emulsion, natural gas, casing gas, instrument air and start-up fluid lines (hereinafter collectively referred to as service lines) and regulatory purposes. The first inlet module 102a minimizes the spacing required for piping, mechanical and electrical connections. Standardized connections allow for mating-up between the service lines connected to the first inlet module 102a and the respective service lines connected to the second inlet module 102b. The standardized connections thus, allow for predictable connectivity in any conceivable well pad design. In any combination of the well-pad system modules, only one first inlet module 102a is required.
The first inlet module 102a functions as the interface between the interconnecting pipelines to and from the CPF and interconnecting pipelines from other support structures. An emulsion line and a casing gas line are connected to one end and one side of the first inlet module 102a.
Emulsion and casing gas produced by each production well (p) in the well-pairs 108-116 (FIG. 1) enter one end of the first inlet module 102a from the second inlet module 102b and exit one side of the first inlet module 102a to the CPF. A steam line and a natural gas line are also connected to one end and one side of the first inlet module 102a. Steam and natural gas enter one side of the first inlet module 102a from the CPF and exit one end of the first inlet module 102a to the second inlet module 102b. An instrument air-line and a start-up fluid line are connected to one end and opposite sides of the first inlet module 102a. Instrument air and start -up fluid enter opposite sides of the first inlet module 102a from the instrument air package 120 and the start-up package 122, respectively, and exit one end of the first inlet module 102a to the second inlet module 102a. The instrument air entering the first inlet module 102a controls any valves in the first inlet module 102a such as the emergency shutdown valves for the critical steam, emulsion, natural gas, casing gas, and start-up fluid lines at the well pad limits. The first inlet module 102a also includes the required metering for process measurement of steam, emulsion, natural gas, casing gas, instrument air and start-up fluid lines (hereinafter collectively referred to as service lines) and regulatory purposes. The first inlet module 102a minimizes the spacing required for piping, mechanical and electrical connections. Standardized connections allow for mating-up between the service lines connected to the first inlet module 102a and the respective service lines connected to the second inlet module 102b. The standardized connections thus, allow for predictable connectivity in any conceivable well pad design. In any combination of the well-pad system modules, only one first inlet module 102a is required.
[0020] Referring now to FIG. 3, a schematic sectional view of the second inlet module 102b in FIG. 1 illustrates standardized connections to the second inlet module 102b. An emulsion line and a casing gas line are connected each end of the second inlet module 102b.
Emulsion and casing gas produced by each production well (p) in the well-pairs 108-116 (FIG.
1) enter one end of the second inlet module 102b from the 1 well-pair module 104 or the 2 well-pair module 106 and exit the other end of the second inlet module 102b to the first inlet module 102a. A steam line, a natural gas line, an instrument-air line and a start-up fluid line are also connected to each end of the second inlet module 102b. Steam, natural gas, instrument air and start-up fluid enter one end of the second inlet module 102b from the first inlet module 102a and exit the other end of the second inlet module 102b to the 1 well-pair module 104 or the 2 well-pair module 106. The instrument air entering the first second module 102b controls any valves in the second inlet module 102b such as the emergency shutdown valves for the critical steam, emulsion, natural gas, casing gas, and start-up fluid lines at the well pad limits. The second inlet module 102b also includes the required metering for process measurement of steam, emulsion, natural gas, casing gas, instrument air and start-up fluid lines and regulatory purposes. The second inlet module 102b minimizes the spacing required for piping, mechanical and electrical connections. Standardized connections allow for mating-up between the service lines connected to the second inlet module 102b and the respective service lines connected to the first inlet module 102a and the 1 well-pair module 104 or the 2 well-pair module 106. The standardized connections thus, allow for predictable connectivity in any conceivable well pad design. In any combination of the well-pad system modules, only one second inlet module 102b is required.
Emulsion and casing gas produced by each production well (p) in the well-pairs 108-116 (FIG.
1) enter one end of the second inlet module 102b from the 1 well-pair module 104 or the 2 well-pair module 106 and exit the other end of the second inlet module 102b to the first inlet module 102a. A steam line, a natural gas line, an instrument-air line and a start-up fluid line are also connected to each end of the second inlet module 102b. Steam, natural gas, instrument air and start-up fluid enter one end of the second inlet module 102b from the first inlet module 102a and exit the other end of the second inlet module 102b to the 1 well-pair module 104 or the 2 well-pair module 106. The instrument air entering the first second module 102b controls any valves in the second inlet module 102b such as the emergency shutdown valves for the critical steam, emulsion, natural gas, casing gas, and start-up fluid lines at the well pad limits. The second inlet module 102b also includes the required metering for process measurement of steam, emulsion, natural gas, casing gas, instrument air and start-up fluid lines and regulatory purposes. The second inlet module 102b minimizes the spacing required for piping, mechanical and electrical connections. Standardized connections allow for mating-up between the service lines connected to the second inlet module 102b and the respective service lines connected to the first inlet module 102a and the 1 well-pair module 104 or the 2 well-pair module 106. The standardized connections thus, allow for predictable connectivity in any conceivable well pad design. In any combination of the well-pad system modules, only one second inlet module 102b is required.
[0021] Referring now to FIG. 4, a schematic sectional view of the 1 well-pair module 104 in FIG. 1 illustrates standardized connections to the 1 well-pair module 104. An emulsion line and a casing gas line are connected to each end of the 1 well-pair module 104. Alternatively, an emulsion line and a casing gas line may be connected to only one end of the 1 well-pair module 104 when it is the last module on the end of a modular well-pad system.
Emulsion and casing gas produced by each production well (p) in the well-pairs 108-116 (FIG. 1) enter the 1 well-pair module 104 from another 1 well-pair module 104, the 2 well-pair module 106 and/or another emulsion line and casing gas line connected to the production side of the 1 well-pair module 104 from each production well. The emulsion and casing gas exit the 1 well-pair module 104 to the second inlet module 102b, another 1 well-pair module 104 or the 2 well-pair module 106. A steam line, a natural gas line, an instrument-air line and a start-up fluid line are also connected to each end of the 1 well-pair module 104. Alternatively, a steam line, a natural gas line, an instrument-air line and a start-up fluid line may be connected to only one end of the 1 well-pair module 104 when it is the last module on the end of a modular well-pad system. Steam, natural gas, instrument air and start-up fluid enter the 1 well-pair module 104 from the second inlet module 102b, another 1 well-pair module 104 or the 3 well-pair module 106. The instrument air entering the 1 well-pair module 104 controls any valves in the 1 well-pair module 104 and exits the 1 well-pair module 104 to another 1 well-pair module 104 or the 2 well-pair module 106. Steam and natural gas exit the 1 well-pair module 104 to another 1 well-pair module 104, the 2 well-pair module 106 and/or another steam line and natural gas line connected to the injection side and the production side of the 1 well-pair module 104 from each respective injection well and production well. Steam is used to form a steam chamber below each injection well and each production well as part of the SAGD process. Natural gas is used as blanket gas for each injection well and each production well. Start-up fluid also exits the 1 well-pair module 104 to another 1 well-pair module 104, the 2 well-pair module 106 and/or another start-up fluid line connected to the injection side of the 1 well-pair module 104 from each respective injection well. The start-up fluid may be used to support the formation of a steam chamber below each injection well as part of the SAGD process. The 1 well-pair module 104 contains the process piping and controls necessary to supply steam to each injection well and receive emulsion from each production well. Each injection well and production well are connected to the 1 well-pair module 104 by a respective pre-fabricated piping spool (not shown), which includes swivel joints. The 1 well-pair module 104 minimizes the spacing required for piping, mechanical and electrical connections. Standardized connections allow for mating-up between the service lines connected to the 1 well-pair module 104 and the respective service lines connected to the second inlet module 102b, another 1 well-pair module 104 and/or the 2 well-pair module 106. The standardized connections allow for predictable connectivity in any conceivable well pad design.
The 1 well pair module 104 may thus, be combined with the first inlet module 102a, the second inlet module 102b and the 2 well-par module 106 in any quantity or combination to achieve a modular well-pad system that can accommodate one to twelve well- pairs on a well pad. For example, five well-pairs may contain five 1 well-pair modules 104, one 2 well-pair module 106 and three 1 well-pair modules 104 or two 2 well-pair modules 106 and one 1 well-pair module 104 as illustrated in FIG. 1.
Emulsion and casing gas produced by each production well (p) in the well-pairs 108-116 (FIG. 1) enter the 1 well-pair module 104 from another 1 well-pair module 104, the 2 well-pair module 106 and/or another emulsion line and casing gas line connected to the production side of the 1 well-pair module 104 from each production well. The emulsion and casing gas exit the 1 well-pair module 104 to the second inlet module 102b, another 1 well-pair module 104 or the 2 well-pair module 106. A steam line, a natural gas line, an instrument-air line and a start-up fluid line are also connected to each end of the 1 well-pair module 104. Alternatively, a steam line, a natural gas line, an instrument-air line and a start-up fluid line may be connected to only one end of the 1 well-pair module 104 when it is the last module on the end of a modular well-pad system. Steam, natural gas, instrument air and start-up fluid enter the 1 well-pair module 104 from the second inlet module 102b, another 1 well-pair module 104 or the 3 well-pair module 106. The instrument air entering the 1 well-pair module 104 controls any valves in the 1 well-pair module 104 and exits the 1 well-pair module 104 to another 1 well-pair module 104 or the 2 well-pair module 106. Steam and natural gas exit the 1 well-pair module 104 to another 1 well-pair module 104, the 2 well-pair module 106 and/or another steam line and natural gas line connected to the injection side and the production side of the 1 well-pair module 104 from each respective injection well and production well. Steam is used to form a steam chamber below each injection well and each production well as part of the SAGD process. Natural gas is used as blanket gas for each injection well and each production well. Start-up fluid also exits the 1 well-pair module 104 to another 1 well-pair module 104, the 2 well-pair module 106 and/or another start-up fluid line connected to the injection side of the 1 well-pair module 104 from each respective injection well. The start-up fluid may be used to support the formation of a steam chamber below each injection well as part of the SAGD process. The 1 well-pair module 104 contains the process piping and controls necessary to supply steam to each injection well and receive emulsion from each production well. Each injection well and production well are connected to the 1 well-pair module 104 by a respective pre-fabricated piping spool (not shown), which includes swivel joints. The 1 well-pair module 104 minimizes the spacing required for piping, mechanical and electrical connections. Standardized connections allow for mating-up between the service lines connected to the 1 well-pair module 104 and the respective service lines connected to the second inlet module 102b, another 1 well-pair module 104 and/or the 2 well-pair module 106. The standardized connections allow for predictable connectivity in any conceivable well pad design.
The 1 well pair module 104 may thus, be combined with the first inlet module 102a, the second inlet module 102b and the 2 well-par module 106 in any quantity or combination to achieve a modular well-pad system that can accommodate one to twelve well- pairs on a well pad. For example, five well-pairs may contain five 1 well-pair modules 104, one 2 well-pair module 106 and three 1 well-pair modules 104 or two 2 well-pair modules 106 and one 1 well-pair module 104 as illustrated in FIG. 1.
[0022] Referring now to FIG. 5, a schematic sectional view of the 2 well-pair module 106 in FIG. 1 illustrates standardized connections to the 2 well-pair module 106. An emulsion line and a casing gas line are connected to each end of the 2 well-pair module 106. Alternatively, an emulsion line and a casing gas line may be connected to only one end of the 2 well-pair module 106 when it is the last module on the end of a modular well-pad system.
Emulsion and casing gas produced by each production well (p) in the well-pairs 108-116 (FIG. 1) enter the 2 well-pair module 106 from the 1 well-pair module 104, another 2 well-pai2 module 106 and/or another emulsion line and casing gas line connected to the production side of the 2 well-pair module 106 from each production well. The emulsion and casing gas exit the 2 well-pair module 106 to the second inlet module 102b, the I well-pair module 104 or another 2 well-pair module 106. A steam line, a natural gas line, an instrument-air line and a start-up fluid line are also connected to each end of the 2 well-pair module 106. Alternatively, a steam line, a natural gas line, an instrument-air line and a start-up fluid line may be connected to only one end of the 2 well-pair module 106 when it is the last module on the end of a modular well-pad system. Steam, natural gas, instrument air and start-up fluid enter the 2 well-pair module 106 from the second inlet module 102b, the I well-pair module 104 or another 2 well-pair module 106. The instrument air entering the 2 well-pair module 106 controls any valves in the 2 well-pair module 106 and exits the 2 well-pair module 106 to the I well-pair module 104 or another 2 well-pair module 106. Steam and natural gas exit the 2 well-pair module 106 to the 1 well-pair module 104, another 2 well-pair module 106 and/or another steam line and natural gas line connected to the injection side and the production side of the 2 well-pair module 106 from each respective injection well and production well. Steam is used to form a steam chamber below each injection well and each production well as part of the SAGD process. Natural gas is used as blanket gas for each injection well and each production well. Start-up fluid also exits the 2 well-pair module 106 to the 1 well-pair module 104, another 2 well-pair module 106 and/or another start-up fluid line connected to the injection side of the 2 well-pair module 106 from each respective injection well. The start-up fluid may be used to support the formation of a steam chamber below each injection well as part of the SAGD process. The 2 well-pair module 106 contains the process piping and controls necessary to supply steam to each injection well and receive emulsion from each production well. Each injection well and production well are connected to the 2 well-pair module 106 by a respective pre-fabricated piping spool (not shown), which includes swivel joints. The 2 well-pair module 106 minimizes the spacing required for piping, mechanical and electrical connections. Standardized connections allow for mating-up between the service lines connected to the 2 well-pair module 106 and the respective service lines connected to the second inlet module 102b, the 1 well-pair module 104 and/or another 2 well-pair module 106. The standardized connections allow for predictable connectivity in any conceivable well pad design.
The 2 well pair module 106 may thus, be combined with the first inlet module 102a, the second inlet module 102b, and the 1 well-par module 104 in any quantity or combination to achieve a modular well-pad system that can accommodate one to twelve well- pairs on a well pad. For example, five well-pairs may contain five 1 well-pair modules 104, one 2 well-pair module 106 and three I well-pair modules 104 or two 2 well-pair modules 106 and one 1 well-pair module 104 as illustrated in FIG. 1.
Emulsion and casing gas produced by each production well (p) in the well-pairs 108-116 (FIG. 1) enter the 2 well-pair module 106 from the 1 well-pair module 104, another 2 well-pai2 module 106 and/or another emulsion line and casing gas line connected to the production side of the 2 well-pair module 106 from each production well. The emulsion and casing gas exit the 2 well-pair module 106 to the second inlet module 102b, the I well-pair module 104 or another 2 well-pair module 106. A steam line, a natural gas line, an instrument-air line and a start-up fluid line are also connected to each end of the 2 well-pair module 106. Alternatively, a steam line, a natural gas line, an instrument-air line and a start-up fluid line may be connected to only one end of the 2 well-pair module 106 when it is the last module on the end of a modular well-pad system. Steam, natural gas, instrument air and start-up fluid enter the 2 well-pair module 106 from the second inlet module 102b, the I well-pair module 104 or another 2 well-pair module 106. The instrument air entering the 2 well-pair module 106 controls any valves in the 2 well-pair module 106 and exits the 2 well-pair module 106 to the I well-pair module 104 or another 2 well-pair module 106. Steam and natural gas exit the 2 well-pair module 106 to the 1 well-pair module 104, another 2 well-pair module 106 and/or another steam line and natural gas line connected to the injection side and the production side of the 2 well-pair module 106 from each respective injection well and production well. Steam is used to form a steam chamber below each injection well and each production well as part of the SAGD process. Natural gas is used as blanket gas for each injection well and each production well. Start-up fluid also exits the 2 well-pair module 106 to the 1 well-pair module 104, another 2 well-pair module 106 and/or another start-up fluid line connected to the injection side of the 2 well-pair module 106 from each respective injection well. The start-up fluid may be used to support the formation of a steam chamber below each injection well as part of the SAGD process. The 2 well-pair module 106 contains the process piping and controls necessary to supply steam to each injection well and receive emulsion from each production well. Each injection well and production well are connected to the 2 well-pair module 106 by a respective pre-fabricated piping spool (not shown), which includes swivel joints. The 2 well-pair module 106 minimizes the spacing required for piping, mechanical and electrical connections. Standardized connections allow for mating-up between the service lines connected to the 2 well-pair module 106 and the respective service lines connected to the second inlet module 102b, the 1 well-pair module 104 and/or another 2 well-pair module 106. The standardized connections allow for predictable connectivity in any conceivable well pad design.
The 2 well pair module 106 may thus, be combined with the first inlet module 102a, the second inlet module 102b, and the 1 well-par module 104 in any quantity or combination to achieve a modular well-pad system that can accommodate one to twelve well- pairs on a well pad. For example, five well-pairs may contain five 1 well-pair modules 104, one 2 well-pair module 106 and three I well-pair modules 104 or two 2 well-pair modules 106 and one 1 well-pair module 104 as illustrated in FIG. 1.
[0023] Those skilled in the art will appreciate that the first inlet module 102a, the second inlet module 102b, the 1 well-pair module 104 and the 2 well-pair module 106 may include many possible different internal configurations of piping, mechanical and electrical components.
If, for example, these modules needed to support a water flood reservoir support design (high pressure water injection downhole), then each steam line would be replaced with high pressure water line (with suitable controls) and each emulsion line would be replaced with another reservoir production fluid line such as a water, solution gas or oil line.
Suitable controls for these new lines may require electrical actuation in which the instrument-air line may be replaced with an electrical line. In these cases the piping may vary at the Christmas tree accordingly.
If, for example, these modules needed to support a water flood reservoir support design (high pressure water injection downhole), then each steam line would be replaced with high pressure water line (with suitable controls) and each emulsion line would be replaced with another reservoir production fluid line such as a water, solution gas or oil line.
Suitable controls for these new lines may require electrical actuation in which the instrument-air line may be replaced with an electrical line. In these cases the piping may vary at the Christmas tree accordingly.
[0024] While the present disclosure has been described in connection with presently preferred embodiments, it will be understood by those skilled in the art that it is not intended to limit the disclosure to those embodiments. It is therefore, contemplated that various alternative embodiments and modifications may be made to the disclosed embodiments without departing from the spirit and scope of the disclosure defined by the equivalents thereof.
Claims (14)
1. A modular well-pad system, comprising:
an inlet module comprising a plurality of service lines, wherein one or more of the plurality of service lines is connected at one side of the inlet module to a central processing facility and the plurality of service lines is connected at another end of the inlet module to a respective plurality of service lines connected to one end of another inlet module, the plurality of service lines connected to the one end of the another inlet module connectable at another end to a respective plurality of service lines connected to one end of a 1 well-pair module and a respective plurality of service lines connected to one end of a 2 well-pair module;
at least one of the 1 well-pair module and the 2 well-pair module, wherein the plurality of service lines connected to the one end of the 1 well-pair module and the plurality of service lines connected to the one end of the 2 well-pair module are connectable to i) a respective plurality of service lines connected to another end of the 1 well-pair module or a respective plurality of service lines connected to another end of the 2 well-pair module, and ii) a respective plurality of service lines connected to another end of another 1 well-pair module and a respective plurality of service lines connected to another end of another 2 well-pair module, and wherein the plurality of service lines connected to the another end of the 1 well-pair module and the plurality of service lines connected to the another end of 2 well-pair module are connectable to a respective plurality of service lines connected to one end of another 1 well-pair module and a respective plurality of service lines connected to one end of another 2 well-pair module; and the 1 well-pair module connectable to one well pair and the 2 well-pair module connectable to two well pairs, wherein each well pair represents an injection well and a production well.
an inlet module comprising a plurality of service lines, wherein one or more of the plurality of service lines is connected at one side of the inlet module to a central processing facility and the plurality of service lines is connected at another end of the inlet module to a respective plurality of service lines connected to one end of another inlet module, the plurality of service lines connected to the one end of the another inlet module connectable at another end to a respective plurality of service lines connected to one end of a 1 well-pair module and a respective plurality of service lines connected to one end of a 2 well-pair module;
at least one of the 1 well-pair module and the 2 well-pair module, wherein the plurality of service lines connected to the one end of the 1 well-pair module and the plurality of service lines connected to the one end of the 2 well-pair module are connectable to i) a respective plurality of service lines connected to another end of the 1 well-pair module or a respective plurality of service lines connected to another end of the 2 well-pair module, and ii) a respective plurality of service lines connected to another end of another 1 well-pair module and a respective plurality of service lines connected to another end of another 2 well-pair module, and wherein the plurality of service lines connected to the another end of the 1 well-pair module and the plurality of service lines connected to the another end of 2 well-pair module are connectable to a respective plurality of service lines connected to one end of another 1 well-pair module and a respective plurality of service lines connected to one end of another 2 well-pair module; and the 1 well-pair module connectable to one well pair and the 2 well-pair module connectable to two well pairs, wherein each well pair represents an injection well and a production well.
2. The system of claim 1, further comprising six interconnected 2 well-pair modules located within a well-pad boundary of the modular well-pad system.
3. The system of claim 1, further comprising three interconnected 2 well-pair modules and six interconnected 1 well-pair modules located within a well-pad boundary of the modular well-pad system.
4. The system of claim 1, wherein the inlet module, the 1 well-pair module and the 2 well-pair module are transportable by rail and truck.
5. The system of claim 1, wherein each plurality of service lines comprises a steam or high pressure water line, a natural gas line, an instrument control line, a production line, a casing gas line and a start-up fluid line.
6. The system of claim 5, wherein the production line includes one of emulsion, water, solution gas and oil.
7. The system of claim 5, wherein the instrument control line includes one of electricity and air.
8. The system of claim 5, wherein the production line, the casing gas line, the natural gas line and the steam or high pressure water line are connected at the one end of the inlet module to the central processing facility and the instrument control line and start-up fluid lines are connected to opposite sides of the inlet module.
9. The system of claim 5, wherein the 1 well-pair module and the 2 well-pair module each comprise another production line and another casing gas line connected at a production side of each respective 1 well-pair module and 2 well-pair module to each respective production well.
10. The system of claim 9, wherein the 1 well-pair module and the 2 well-pair module each comprise another natural gas line and another steam or high pressure water line connected at an injection side and the production side of each respective 1 well-pair module and 2 well-pair module to each respective injection well and each respective production well.
11. The system of claim 10, wherein the 1 well-pair module and the 2 well-pair module each comprise another start-up fluid line connected at the injection side of each respective 1 well-pair module and 2 well-pair module to each respective injection well.
12. The system of claim 6, further comprising an electric submersible pump positioned below each production well.
13. The system of claim 12, wherein the emulsion, water, solution gas and oil are each a single phase liquid product.
14. The system of claim 1, wherein each connection is standardized.
Applications Claiming Priority (3)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US201662294477P | 2016-02-12 | 2016-02-12 | |
| US62/294,477 | 2016-02-12 | ||
| PCT/IB2017/000191 WO2017137846A1 (en) | 2016-02-12 | 2017-02-10 | Modular well pad systems and methods |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CA3014272A1 CA3014272A1 (en) | 2017-08-17 |
| CA3014272C true CA3014272C (en) | 2020-09-01 |
Family
ID=59563709
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA3014272A Active CA3014272C (en) | 2016-02-12 | 2017-02-10 | Modular well pad systems and methods |
Country Status (3)
| Country | Link |
|---|---|
| US (1) | US20190048700A1 (en) |
| CA (1) | CA3014272C (en) |
| WO (1) | WO2017137846A1 (en) |
Family Cites Families (8)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| EP1353038A1 (en) * | 2002-04-08 | 2003-10-15 | Cooper Cameron Corporation | Subsea process assembly |
| US7448447B2 (en) * | 2006-02-27 | 2008-11-11 | Schlumberger Technology Corporation | Real-time production-side monitoring and control for heat assisted fluid recovery applications |
| US7647976B2 (en) * | 2006-04-21 | 2010-01-19 | Maoz Betzer Tsilevich | System and method for steam-assisted gravity drainage (SAGD)-based heavy oil well production |
| CA2654848C (en) * | 2009-02-20 | 2013-10-01 | Suncor Energy Inc. | Modular wellpad construction system |
| US8474521B2 (en) * | 2011-01-13 | 2013-07-02 | T-3 Property Holdings, Inc. | Modular skid system for manifolds |
| CA2797368C (en) * | 2012-11-27 | 2015-11-24 | Laricina Energy Ltd. | Sagd container wellpad assembly |
| CA2875579C (en) * | 2014-04-17 | 2016-02-16 | Timothy Webber | System and method for steam-assisted gravity drainage (sagd)-based heavy oil well production |
| CA2974022C (en) * | 2015-04-24 | 2022-09-13 | Integrated Thermal Solutions Ltd. | A pad drilling method for drilling multiple wells and a multi-well pad system employing the same |
-
2017
- 2017-02-10 CA CA3014272A patent/CA3014272C/en active Active
- 2017-02-10 US US16/077,279 patent/US20190048700A1/en not_active Abandoned
- 2017-02-10 WO PCT/IB2017/000191 patent/WO2017137846A1/en active Application Filing
Also Published As
| Publication number | Publication date |
|---|---|
| US20190048700A1 (en) | 2019-02-14 |
| WO2017137846A1 (en) | 2017-08-17 |
| CA3014272A1 (en) | 2017-08-17 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| US8500419B2 (en) | Subsea pumping system with interchangable pumping units | |
| US10900475B2 (en) | Distribution unit | |
| US8083501B2 (en) | Subsea pumping system including a skid with wet matable electrical and hydraulic connections | |
| US9127545B2 (en) | Delivery system for fracture applications | |
| RU2416712C2 (en) | Underwater device (versions) and procedure for transporting well fluid | |
| RU2668611C2 (en) | Underwater well fluid conditions treatment | |
| AU2003241367B2 (en) | System and method for flow/pressure boosting in subsea | |
| RU2638199C9 (en) | Underwater treatment of wellbore fluids | |
| CA2999306A1 (en) | Modular fracturing pad structure | |
| US9920597B2 (en) | System for subsea pumping or compressing | |
| US20100119380A1 (en) | Subsea pumping system | |
| BR112013025880A2 (en) | method for supplying fracturing fluid to a wellbore, system for use in supplying pressurized fluid to a wellbore, and electrical mixing apparatus used in fracturing operations | |
| US9856630B2 (en) | Mixing systems for water storage tanks | |
| US7513934B2 (en) | Micro processing system for multi-phase flow | |
| CA3014272C (en) | Modular well pad systems and methods | |
| CA3014562C (en) | Modular well pad systems and methods | |
| Eriksen et al. | Pazflor SSPS Project; Testing and Qualification of Novel Technology: A Key to Success | |
| RU2189439C2 (en) | Method of developing oil deposits and block complex system of plants for method embodiment | |
| CA2797368A1 (en) | Sagd container wellpad assembly | |
| CA3057354A1 (en) | Re-deployable well-pad facility and method therefor | |
| RU2514454C1 (en) | Station for transfer and separation of multiphase mix | |
| RU139482U1 (en) | OIL AND GAS COLLECTION STATION | |
| BRPI0504586B1 (en) | subsea heating module for hydrocarbon production and method for subsea storage and replacement |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| EEER | Examination request |
Effective date: 20180810 |