US20190345802A1 - Temperature Responsive Fracturing - Google Patents
Temperature Responsive Fracturing Download PDFInfo
- Publication number
- US20190345802A1 US20190345802A1 US16/261,687 US201916261687A US2019345802A1 US 20190345802 A1 US20190345802 A1 US 20190345802A1 US 201916261687 A US201916261687 A US 201916261687A US 2019345802 A1 US2019345802 A1 US 2019345802A1
- Authority
- US
- United States
- Prior art keywords
- temperature
- casing
- temperature responsive
- perforating
- sleeve
- 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.)
- Abandoned
Links
- 239000002360 explosive Substances 0.000 claims abstract description 53
- 238000002955 isolation Methods 0.000 claims abstract description 50
- 230000007246 mechanism Effects 0.000 claims abstract description 50
- 239000012530 fluid Substances 0.000 claims abstract description 29
- 238000004891 communication Methods 0.000 claims abstract description 25
- 239000000126 substance Substances 0.000 claims abstract description 7
- 238000005520 cutting process Methods 0.000 claims abstract description 4
- 230000002457 bidirectional effect Effects 0.000 claims description 5
- 239000003990 capacitor Substances 0.000 claims description 4
- 238000003466 welding Methods 0.000 claims description 2
- 230000000977 initiatory effect Effects 0.000 abstract description 12
- 238000000034 method Methods 0.000 description 25
- 238000005086 pumping Methods 0.000 description 24
- 210000003371 toe Anatomy 0.000 description 24
- 230000015572 biosynthetic process Effects 0.000 description 19
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 14
- 238000013461 design Methods 0.000 description 12
- 230000001960 triggered effect Effects 0.000 description 10
- 208000010392 Bone Fractures Diseases 0.000 description 9
- 206010017076 Fracture Diseases 0.000 description 9
- 239000004568 cement Substances 0.000 description 9
- 238000012546 transfer Methods 0.000 description 9
- 230000008569 process Effects 0.000 description 8
- 229910000831 Steel Inorganic materials 0.000 description 5
- 239000010959 steel Substances 0.000 description 5
- 238000005474 detonation Methods 0.000 description 4
- 230000004888 barrier function Effects 0.000 description 3
- 230000006870 function Effects 0.000 description 3
- 238000002347 injection Methods 0.000 description 3
- 239000007924 injection Substances 0.000 description 3
- 239000000463 material Substances 0.000 description 3
- 239000004576 sand Substances 0.000 description 3
- 230000000638 stimulation Effects 0.000 description 3
- 238000004880 explosion Methods 0.000 description 2
- 238000004519 manufacturing process Methods 0.000 description 2
- 239000002184 metal Substances 0.000 description 2
- 230000037361 pathway Effects 0.000 description 2
- 230000006903 response to temperature Effects 0.000 description 2
- 239000011435 rock Substances 0.000 description 2
- 239000000243 solution Substances 0.000 description 2
- 239000002253 acid Substances 0.000 description 1
- 239000002131 composite material Substances 0.000 description 1
- 230000006835 compression Effects 0.000 description 1
- 238000007906 compression Methods 0.000 description 1
- 238000010276 construction Methods 0.000 description 1
- 230000001351 cycling effect Effects 0.000 description 1
- 230000001419 dependent effect Effects 0.000 description 1
- 238000010586 diagram Methods 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 239000000446 fuel Substances 0.000 description 1
- 210000001255 hallux Anatomy 0.000 description 1
- 238000010438 heat treatment Methods 0.000 description 1
- 239000004615 ingredient Substances 0.000 description 1
- 238000009413 insulation Methods 0.000 description 1
- 238000012423 maintenance Methods 0.000 description 1
- 230000001483 mobilizing effect Effects 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 238000002360 preparation method Methods 0.000 description 1
- 230000000135 prohibitive effect Effects 0.000 description 1
- 239000003380 propellant Substances 0.000 description 1
- 239000002352 surface water Substances 0.000 description 1
- 238000012360 testing method Methods 0.000 description 1
- FQFKTKUFHWNTBN-UHFFFAOYSA-N trifluoro-$l^{3}-bromane Chemical compound FBr(F)F FQFKTKUFHWNTBN-UHFFFAOYSA-N 0.000 description 1
Images
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
- E21B43/25—Methods for stimulating production
- E21B43/26—Methods for stimulating production by forming crevices or fractures
-
- 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
- E21B43/25—Methods for stimulating production
- E21B43/26—Methods for stimulating production by forming crevices or fractures
- E21B43/263—Methods for stimulating production by forming crevices or fractures using explosives
-
- 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
- E21B29/00—Cutting or destroying pipes, packers, plugs, or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windows; Deforming of pipes in boreholes or wells; Reconditioning of well casings while in the ground
- E21B29/02—Cutting or destroying pipes, packers, plugs, or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windows; Deforming of pipes in boreholes or wells; Reconditioning of well casings while in the ground by explosives or by thermal or chemical means
-
- 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
- E21B34/00—Valve arrangements for boreholes or wells
- E21B34/06—Valve arrangements for boreholes or wells in 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
- E21B43/11—Perforators; Permeators
- E21B43/116—Gun or shaped-charge perforators
- E21B43/117—Shaped-charge perforators
-
- 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
- E21B43/2405—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection in association with fracturing or crevice forming processes
-
- 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
- E21B43/25—Methods for stimulating production
- E21B43/26—Methods for stimulating production by forming crevices or fractures
- E21B43/261—Separate steps of (1) cementing, plugging or consolidating and (2) fracturing or attacking the formation
-
- 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
- E21B47/00—Survey of boreholes or wells
- E21B47/06—Measuring temperature or pressure
- E21B47/07—Temperature
-
- E21B2034/007—
-
- 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
- E21B2200/00—Special features related to earth drilling for obtaining oil, gas or water
- E21B2200/06—Sleeve valves
-
- 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
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/10—Sealing or packing boreholes or wells in the borehole
- E21B33/12—Packers; Plugs
-
- 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
- E21B34/00—Valve arrangements for boreholes or wells
- E21B34/06—Valve arrangements for boreholes or wells in wells
- E21B34/066—Valve arrangements for boreholes or wells in wells electrically actuated
-
- 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
- E21B34/00—Valve arrangements for boreholes or wells
- E21B34/06—Valve arrangements for boreholes or wells in wells
- E21B34/14—Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
-
- 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
- E21B43/25—Methods for stimulating production
- E21B43/26—Methods for stimulating production by forming crevices or fractures
- E21B43/267—Methods for stimulating production by forming crevices or fractures reinforcing fractures by propping
Abstract
Fracturing a well can include disposing within the well a plurality of temperature responsive devices including a trigger circuit. The devices may be configured to establish fluid communication through a casing of the well or isolate a section of the well responsive to a downhole temperature, a number of downhole temperature cycles, and/or a time delay. The devices may operate by triggering an explosive and/or initiating at least one of a thermal, incendiary, or chemical cutting device. The devices can perforating sleeves adapted to be installed over a casing joint, subs adapted to be threaded between two casing joints, perforating devices embedded within a casing joint, isolation mechanisms, or toe valves.
Description
- Horizontal shale wells have historically required pumping large volumes of water and sand to fracture the rock. The effectiveness of the fracturing may rely on a series of independent stages that are isolated from each other by pressure barriers. The method of isolation can vary from well to well, but the industry has gravitated towards plug and perf operations due to positive correlations between the number of fracture initiation points and well production. To create fracture initiation points, a tubular metal wire line gun may be loaded with explosives, then pumped from the surface to a desired downhole location where the charges may be set off by sending an electrical signal down the wire from surface. The electric signal can selectively set off the detonators (the primary explosive) that may be connected to the charges via a primer cord. A plug may be run in the hole below the perforating guns and set before the first gun of each stage is fired, thereby isolating the previous stage from the next stage to be fractured. Each stage may be defined by a set of individual clusters and a total amount of water and sand that is pumped downhole simultaneously into the clusters. Mechanically, the steps of this process have remained relatively unchanged since wire line pump down operations began.
- While the basic steps of the perforating process have not changed, many details of the process have. For example, operators have discovered that increasing the number of fracture initiation points by pumping significantly more sand and water into more clusters can increase the value of the production streams beyond the associated added costs. As a result, the number of clusters per fracture stage, the number of stages, and thus the total number of clusters per well has increased significantly over time.
- As the number of stages has increased, it has become increasingly important to reduce the amount of time between stages. When a single well is fractured, the entire hydraulic fracture equipment spread must wait for the wire line operation to finish so that pumping can begin. This could be up to 2.5 hours or more for the deepest stages in a well. When two wells are zipper fractured (one is being fractured while the other undergoes wire line operations), this time can be reduced to 30 to 90 minutes depending on onsite procedures and equipment maintenance. However, in some cases, theoretical time savings from zipper fracturing wells may not be achieved because as the fracturing spread is run more consistently, wear and tear on the fluid ends of the frac pumps increases, which may result in minimal or negative savings from zippering the wells.
- Fracturing initiation for the toe stage via toe valves can also present issues. First, toe valves may fail to open, or they may open and then become clogged with debris. In some cases operators may elect to perform a “toe preparation” process that involves mobilizing equipment to site and making sure that the toe valves work so that the more expensive hydraulic fracturing spread will not be forced to wait on malfunctioning toe valves. Toe valves can also restrict the inner diameter of the casing near the toe, necessitating more flexible wiper darts to be run, which can increase the chances of leaving excess cement in the well bore.
- As an alternative to toe valves, some operators may perforate the toe of the well by running guns in the well on coiled tubing, a process known as TCP (tubing conveyed perforating). Using TCP, the operator can shoot the total desired number of clusters in the first stage, resulting in one fewer wire line trip to achieve the same total number of clusters in the well. TCP can also give more entry points into the well so that operators are less likely to plug off the openings with debris. Running TCP can also eliminate the need for casing ID restrictions at the toe of the well, increasing the likelihood of a successful cement job. However, TCP is dependent on coiled tubing availability and can be expensive. TCP may also not be able to reach deep enough to reach the toe of some extended lateral wells due to frictional limitations.
- The foregoing challenges have led service companies to try alternative fracturing methods to replace the plug and perf process. However, the new techniques have, in general, been cost prohibitive. For example, pressure actuated sliding sleeves allow operators to move very quickly between stages by dropping a ball to seal off the old stage and shift the next stage's sleeve open. However, the higher number of fracture initiation points and lower cost of plug and perf completion designs rendered sliding sleeves unsuitable for many applications. Coil shifted sleeves have also been used, but such operations are very time consuming; adding moving equipment downhole increases the risk of failure. RFID (radio frequency identification) technology has also been applied to casing conveyed perforating, in which charges are run in on the outside of the casing, but these solutions required composite windows in the casing to allow for RF (radio frequency) communication through the casing. Added cost and complexity rendered this solution impractical as well. Thus, plug and perf remains a preferred industry technique for completing wells.
- Thus, what is needed in the art are improvements to plug and perf completions that simplify operations so as to allow for reduced cost and reduced time.
- A method of fracturing a well can include disposing within the well a plurality of temperature responsive devices each comprising a trigger circuit configured to establish fluid communication through a casing of the well responsive to a downhole temperature and a number of downhole temperature cycles. The method can further include pumping a first frac stage, thereby lowering the downhole temperature for at least a predetermined time period, the lowering of the downhole temperature being detected by each of the trigger circuits. The method can further include stopping pumping of the first frac stage, thereby allowing the downhole temperature to increase, the increased temperature being detected by each of the trigger circuits. Each temperature responsive device, upon detecting a respective predetermined number of temperature cycles and a downhole temperature exceeding a respective predetermined temperature, can trigger establishment of fluid communication through the casing.
- The downhole temperature can be at least one of a casing temperature or a wellbore fluid temperature. At least one of the plurality of temperature responsive device can trigger establishment of fluid communication through the casing by detonating an explosive. Detonating the explosive may create pressure to shift a sleeve or port. Detonating the explosive may further allow well pressure to shift an unbalanced piston. In some embodiments, establishment of fluid communication through the casing may include initiating at least one of a thermal, incendiary, or chemical cutting device.
- The temperature responsive devices may include at least one temperature responsive perforating sleeve adapted to be installed over a casing joint. The temperature responsive devices may include at least one temperature responsive sub adapted to be threaded between two casing joints. The temperature responsive devices may include at least one temperature responsive perforating device embedded within a casing joint.
- The method discussed above may further include disposing within the well at least one temperature responsive isolation mechanism wherein the temperature responsive isolation mechanism is used to form a pressure barrier between frac stages. The isolation mechanism may detonate an explosive, which may, in some embodiments, allow wellbore pressure to act on an unbalanced piston and, in at least some embodiments, create a pressure imbalance to shift a sleeve or port. In some embodiments, the isolation mechanism may create a ball seat.
- The method may still further include, prior to pumping the first frac stage, triggering an explosive device of a temperature responsive device located at a toe of the well, the triggering being responsive to a predetermined amount of time above a predetermined temperature threshold detected by the temperature responsive device located at the toe of the well. In such cases, at least one trigger mechanism may be configured to trigger a respective explosive upon detecting a respective predetermined number of temperature cycles, a casing temperature exceeding a respective predetermined temperature, and a respective time delay.
- A method of fracturing a well may alternatively or additionally include disposing within the well at least one temperature responsive isolation devices each comprising a trigger circuit configured to establish isolation between at least two well zones responsive to a downhole temperature and a number of downhole temperature cycles. The method may further include pumping a first frac stage, thereby lowering the downhole temperature for at least a predetermined time period, the lowering of the downhole temperature being detected by the at least one trigger circuits. The method may still further include stopping pumping of the first frac stage, thereby allowing the downhole temperature to increase, the increased temperature being detected by the at least one trigger circuits. At least one temperature responsive isolation device, upon detecting a respective predetermined number of temperature cycles and a downhole temperature exceeding a respective predetermined temperature, may triggers the isolation mechanism. Triggering the isolation mechanism may detonate an explosive. Detonation of the explosive may allow wellbore pressure to act on an unbalanced piston and may additionally or alternately create a pressure imbalance to shift a sleeve or port. The isolation mechanism creates a ball seat.
- A method of fracturing a well may alternatively or additionally include disposing within the well a temperature responsive toe valve comprising a trigger circuit that opens the valve responsive to a downhole temperature above a predetermined temperature threshold for a predetermined period of time. Subsequent to the predetermined amount of time above a predetermined temperature, one or more frac stages may be pumped. The downhole temperature may be at least one of a casing temperature or a wellbore fluid temperature. The temperature responsive toe valve may open by detonating an explosive, which may create pressure to shift a sleeve or port, which may allow well pressure to shift an unbalanced piston. The temperature responsive toe valve may additionally or alternatively open by initiating at least one of a thermal, incendiary, or chemical cutting device.
- A temperature responsive completion device may include an explosive and a trigger circuit configured to trigger the explosive responsive to a downhole temperature and at least one of a number of temperature cycles and a time period above or below a temperature threshold. The temperature responsive device may be a perforating sleeve adapted to be installed over a casing joint. The perforating sleeve is configured to be secured to the casing by welding, slips, and/or mechanical fasteners. The perforating sleeve may be located with respect to the casing by one or more pre-drilled holes in the casing. In other embodiments, the temperature responsive completion device may be a sub adapted to be threaded between two casing joints.
- The temperature responsive completion device may also be a remote isolation mechanism. The isolation mechanism may detonate an explosive to create a pressure imbalance to shift a sleeve or port, including, for example by use of an unbalanced piston. In some embodiments, the isolation mechanism may create a ball seat.
- The temperature responsive completion device may also be a toe valve. In such embodiments, the trigger circuit may be configured to trigger the explosive responsive to a downhole temperature above a predetermined temperature threshold for a predetermined time period.
- In any of the foregoing embodiments, the trigger circuit may include a temperature sensor, a controller, and a plurality of capacitors. The explosive may be a shaped charge, including a unidirectional shaped charge or a bidirectional shaped charge, and the shaped charge may operate in conjunction with a rupture or burst disk.
-
FIG. 1 illustrates a wellbore apparatus comprising a plurality of frac stages, each including multiple clusters. -
FIG. 2 illustrates wellbore apparatus temperatures for a plurality of frac stages. -
FIGS. 3A-3B illustrate an embodiment of a perforating sleeve. -
FIG. 4 illustrates an alternative embodiment of a perforating sleeve. -
FIG. 5 illustrates another alternative embodiment of a perforating sleeve. -
FIGS. 6A-6D illustrate still another embodiment of a perforating sleeve. -
FIGS. 7A-7E schematically depict the control and actuating aspects of a perforating sleeve. -
FIGS. 8A-8D depict explosives configurations for a perforating sleeve. -
FIGS. 9A-9D depict a perforating sleeve using a pressure actuated piston. -
FIGS. 10A-10B depict an alternative perforating sleeve design using an unbalanced piston. -
FIGS. 11A-11C depict the exterior of a temperature actuated sleeve run as a subassembly with box and pin threads. -
FIGS. 12A-12B depict a sleeve using an unbalanced piston run as a subassembly with box and pin threads. -
FIGS. 13A-13B depict a sleeve using a pressure actuated piston run as a subassembly with box and pin threads. -
FIGS. 14A-14D depict a remote isolation mechanism. -
FIGS. 15A-15F depict the operating sequence of a frac completion using perforating sleeves and remote isolation mechanisms. - In the following description, for purposes of explanation, numerous specific details are set forth to provide a thorough understanding of the disclosed concepts. As part of this description, some of this disclosure's drawings represent structures and devices in block diagram form for sake of simplicity. In the interest of clarity, not all features of an actual implementation are described in this disclosure. Moreover, the language used in this disclosure has been selected for readability and instructional purposes, has not been selected to delineate or circumscribe the disclosed subject matter. Rather the appended claims are intended for such purpose.
- Various embodiments of the disclosed concepts are illustrated by way of example and not by way of limitation in the accompanying drawings in which like references indicate similar elements. For simplicity and clarity of illustration, where appropriate, reference numerals have been repeated among the different figures to indicate corresponding or analogous elements. In addition, numerous specific details are set forth in order to provide a thorough understanding of the implementations described herein. In other instances, methods, procedures and components have not been described in detail so as not to obscure the related relevant function being described. References to “an,” “one,” or “another” embodiment in this disclosure are not necessarily to the same or different embodiment, and they mean at least one. A given figure may be used to illustrate the features of more than one embodiment, or more than one species of the disclosure, and not all elements in the figure may be required for a given embodiment or species. A reference number, when provided in a given drawing, refers to the same element throughout the several drawings, though it may not be repeated in every drawing. The drawings are not to scale unless otherwise indicated, and the proportions of certain parts may be exaggerated to better illustrate details and features of the present disclosure.
-
FIG. 1 schematically depicts a wellbore apparatus that may be used in a plug and perf operation. The wellbore apparatus includes a series of well casing joints 101 a, 101 c, 102 a, 102 c, 103 a, 103 c, and 103 e. These casing joints are joined by a series of perforatingsleeves Perforating sleeve 103 f is located at the “heel” of the wellbore assembly, i.e., at a least distal/nearest the surface end. It will be appreciated that the illustrated wellbore assembly may be located in a vertical segment of the well, a horizontal segment of the well, and that the exact orientation of these segments may in fact be anywhere between truly horizontal and vertical. It will also be appreciated that a well may include multiple lateral segments, each containing a wellbore assembly similar to that illustrated inFIG. 1 , or that the assembly may include more or fewer numbers of casing joints, stimulation zones (described below), and/or perforating sleeves. - So-called “plug and perf” fracturing operations may be enhanced by the use of casing conveyed perforating. In casing conveyed perforating, explosives are run into the well with the casing. For example, the explosives may be disposed in/on perforating sleeves like those described herein. These explosives may be triggered at the desired time to perforate the casing, allowing fluid communication between the well bore and the formation, allowing the initiation of fracturing. Initiating the explosives preferably includes communicating data (i.e., a trigger signal) through the steel casing to the various perforating sleeves disposed within the well. Preferably this communication can be performed without excessive power consumption to either send the initiating signal or receive and respond to the initiating signal on the outside of the casing. One way to achieve this goal is to use the temperature cycles that naturally occur as a part of fracturing operations to encode counter signals that can be received and decoded by receiver circuitry disposed in the perforating sleeve. In some embodiments, these same temperature cycles can be used to remotely actuate isolation mechanisms to provide down hole operations without wire line, coiled tubing, or other intervention from surface. The temperature that is monitored as the control input for this process may be a well casing temperature, a wellbore fluid temperature, or any other suitable downhole temperature. For purposes of the following description, operation of the device will be described in terms of casing temperature, but it will be understood that any other suitable downhole temperature may be used.
- A well's casing experiences temperature swings resulting from the relatively high temperature of the formation versus the relatively low temperature of the hydraulic fracturing water. This may be understood with reference to
FIG. 2 , which illustrates various temperatures associated with a fracturing operation.FIG. 2 illustrates aplot 200 illustrating an exemplary fracturing operation. Time is depicted on the x-axis, and flow rate (for curve 202) and temperature (forcurves Curve 202 represents the flow of fracturing water for three pumping stages (3, 5, 7), with a flow rate of approximately 75 bbl/min during the frac and a flow rate of approximately zero during other times.Curve 204 represents the casing temperature over a corresponding series of non-pumping time periods (2, 4, 6, 8) and the same pumping periods (3, 5, 7). As can be seen, thecasing temperature 204 in time period 2 starts out at a temperature of approximately 250 F, which corresponds to theformation temperature 206. As the first pumping stage (3) begins, the temperature drops rapidly to approximately 80 F, which corresponds to the temperature of the frac water 208. After a predetermined time below the low temperature threshold, the pumping stage may be detected as having been completed. Once the first pumping stage ends, the casing temperature begins increasing (4). Once thecasing temperature 204 exceeds thecounter trigger temperature 210 for a predetermined period of time, an explosive is triggered, opening new holes in the casing and formation, and a further pumping stage (5) begins, which drops thecasing temperature 204 back to the frac water temperature 208. This cycle may repeat multiple times. - In some embodiments, a minimum time at or below a low temperature threshold may be detected and required as a condition of incrementing the cycle count. This time threshold relates to certain operating practices sometimes implemented in fracturing operations. For example, in some cases, pumping of a frac stage may be interrupted because of some operational issue. If, prior to the interruption, less than a certain amount of pumping had occurred, the operator may desire to re-frac the stage, i.e., to continue pumping into the current stage. Alternatively, if more than a certain amount of pumping had occurred, the operator may consider the frac of that stage to be “good enough” and may want to move on to the next stage. Thus, a minimum time at or below a low temperature threshold can allow the operator to either re-frac a current stage or move to the next stage as appropriate.
- The heat transfer model of the casing may be readily understood with respect to the heat transfer coefficients of steel, cement, and shale. Steel has a relatively high heat transfer coefficient of about 43 W/(m-K). Cement has a relatively low heat transfer coefficient of about 0.29 W/(m-K). Shale rock of the formation on the outside of the casing may typically have a heat transfer coefficient higher than the cement but lower than steel. The heat transfer problem may thus be imagined as a pipe (the casing) with water (the fracturing water) flowing through it, wrapped in thermal insulation (cement), surrounded by an infinite heat source (the shale formation). During the pumping stages, because so much water is pumped (sometimes in excess of 5,000 bbls per stage), and because the water is at surface temperature, the steel casing quickly assumes nearly the same temperature as the surface water. The cement is the limiting factor in the heat transfer equation. Because of the insulating properties of the cement, there is never enough heat transferred from the shale formation to warm the casing because of the large amounts of water being pumped during the fracturing job. After a pumping stage is completed, the problem becomes a steady state heat transfer problem. During this non-pumping phase, the shale slowly transfers heat to the casing and the water contained therein, eventually bringing it up to the constant temperature of the shale formation. In the illustration of
FIG. 2 , the temperature after two hours of heating corresponds to the approximately 155 F temperature at the peaks ofcurve 204. - Understanding that the downhole temperatures will follow predictable “drop-then-rise” cycles as a result of frac stages being pumped allows a counter signal to be encoded in each cycle. The fracturing sleeves may use this counter signal, with each stage's set of clusters being individually keyed to send a detonation signal based on these well bore cycles. Certain clusters within a stage may be given a time delay to preferentially open a cluster or clusters in a certain order. This may allow time for other operations. For example, acid may be injected into the toe cluster and placed or “spotted” over the remaining clusters to ensure an efficient wellbore cleanup and stimulation.
- In addition to having applications for use in multi-stage fracturing operations, a temperature actuated device may function to establish initial wellbore injection in the toe of the well, replacing the pressure actuated toe valves used in many wells today. In some wells, a device may be run in the toe of the well and programmed to open a pathway from the casing to the formation after a time delay and temperature threshold are both exceeded. This time delay may serve at least two functions. First, it may give the rig crew ample time to ensure that the casing is successfully run into position before actuation. Second, it may allow the operator time to pressure test casing integrity before beginning injection or fracture stimulation operations. The temperature threshold may be set so that once a certain temperature (corresponding to the well's bottom hole temperature) is exceeded, actuation and communication between the well and the formation is established to allow for the first toe injection stage to commence.
- Turning back to
FIG. 1 , frac stage programming might look like the following, assuming an open toe valve or circulation point at the start.FIG. 1 shows three stages: Stage 1 (101), Stage 2 (102), and Stage 3 (103). Stages 1 and 2 each include two clusters, and stage 3 includes three clusters. (It will be appreciated that an actual implementation may include any number of stages, with each stage including any number of clusters.) In the illustrated embodiment, Stage 1 (101) includes casing joints 101 a and 101 c along with perforatingsleeves sleeves -
- Stage 1: All clusters (i.e., perforating
sleeves FIG. 2 ). - Stage 3: All clusters (i.e., perforating sleeves 102 b and 102 d) may be programmed to fire after two temperature drop and rise cycles (e.g., Zone 6 of
FIG. 2 ). - Stage 3: All clusters (i.e., perforating
sleeves FIG. 2 ).
- Stage 1: All clusters (i.e., perforating
- Thus, the clusters may all be programmed at the same or similar temperature set point (e.g.,
temperature 210 inFIG. 2 ), with the clusters of each stage being set with a different number of temperature cycles triggering the perforating. In some embodiments, temperature set points may vary with well depth as required for a particular application or based on a particular well profile. In any case, this programming methodology allows selective perforating of each stage moving up the well bore. Omitted from the foregoing description is an isolation mechanism between the zones (as may be included in the fracturing operations). A remote isolation mechanism is described below; however, in a simple scenario, balls of different diameters may be dropped from the surfaces and may be caught by ball seats of increasing diameter (up the well) to form pressure seals in the conventional manner. - The perforating sleeves may be designed so as to be conveyed to the target zone of the wellbore along with (i.e., as part of) the well's casing. In some embodiments, the perforating sleeve may be a substantially cylindrical body either comprising a subassembly with box and pin threads so as to be connected between casing joints. In other embodiments, the perforating sleeve may be designed to be slipped over a casing joint and secured in place.
-
FIG. 3A illustrates anexemplary perforating sleeve 300 designed as a subassembly for threading into casing joints.Perforating sleeve 300 has at one end apin thread 301 adapted to mate to a box thread of a first casing joint 304 (FIG. 3B ).Perforating sleeve 300 has at the other end a box thread 302 adapted to mate to a pin thread of a second casing joint 305 (FIG. 3B ).Perforating sleeve 300 also includes aport 303 for access to interior electronics and explosives.Perforating sleeve 300 can be run between regular or shortened casing joints (e.g., 304, 305,FIG. 3B ) as part of the casing string.FIG. 3B illustrates multiple perforatingsleeves joints sleeves 300 may be used, or the perforatingsleeves 300 could be lengthened to accommodate more explosives. The port may be deemed unnecessary in this arrangement and excluded from the sleeve design. -
FIG. 4 illustrates anexemplary perforating sleeve 400 designed as a subassembly for slipping over a casing joint.Perforating sleeve 400 is similar to perforatingsleeve 300, except that the box and pin threads have been omitted. Instead of threading into the end of casing joints, perforatingsleeve 400 is intended to be slipped over acasing joint 401. Thus, perforatingsleeve 400 has an inside diameter that is slightly greater than the outside diameter of the casing with which it is intended to be used. Once perforatingsleeve 400 is positioned at the desired location along casing joint 401, it may be secured to the casing joint bywelds 402, 403. This allows for secure mechanical positioning as well as a pressure tight seal between perforatingsleeve 400 and casing joint 401. -
FIG. 5 illustrates a perforatingsleeve 500 also designed as a subassembly for slipping over acasing joint 501. However, rather than being configured to be welded to the casing joint 501, perforatingsleeve 500 is configured to be secured bymechanical fasteners 504. More specifically, perforatingsleeve 500 may be slipped over casing joint 501 as indicated bydirectional arrows 502. Once in position, a plurality of fasteners 504 (bolts, screws, pins, etc.) may be positioned withinholes 505 drilled through perforatingsleeve 501. Optionally, holes 506 may be provided incasing 501 to provide additional security. Theseholes 506 may be drilled partially through the casing or may be drilled entirely through the casing. Additional seal elements, including either an elastomeric seal, a metal-metal seal, or other types/combinations of seals may also be provided to ensure pressure-tight connection between perforatingsleeve 500 and casing joint 501. -
FIG. 6A illustrates an enlarged, exploded view of yet another perforatingsleeve 600.Perforating sleeve 600 is configured to useslips 602 andseals 604 to secure perforatingsleeve 600 to thecasing 606. The housing of perforatingsleeve 600 includesshoulders 601 andmain chamber 603.Shoulders 601 may be located on either end ofmain chamber 603 and may be angled to facilitate smooth running into the wellbore.Slips 602, located at either end ofmain housing 603 wedge between the interior ofshoulders 601 and casing joint 606 to secure perforatingsleeve 600 to the casing as described in further detail below.Seals 604 may be energized by the same compression that securesslips 602, or they may be self-energized to ensure a pressure tight seal betweenmain chamber 603 andcasing 606. The control electronics and explosives (not pictured) may be contained withinmain chamber 603 and supported byinterior supports 605. These supports may also provide support for casing 606 from burst and collapse pressure. -
FIG. 6B illustrates a cutaway view of perforatingsleeve 600 having the slip and seal design. More specifically,FIG. 6B illustrates a view of the engaged slips 602 and seals 604 together with the configuration of the interior supports 606 mounted insidemain chamber 603.FIG. 6B omits the control electronics, batteries, and explosives for clarity. -
FIG. 6C illustrates perforatingsleeve 600 withmain chamber 603 drawn transparently. This allows one to seecasing 606, andinterior supports 605 and various electronic components (unlabeled) , which allows the capacitors and the circuit board as well as thesupport tray 605, which is disposed around thecasing 606 to be seen. As in the preceding figures, the shoulders are labeled 601 for reference. -
FIG. 6D illustrates a close-up view ofslips 602 andseals 604 as illustrated inFIGS. 6A-6C . With thesleeve 600 positioned in the desired position oncasing 606, slips 602 on either end ofsleeve 600 may be engaged by screwing the shoulder caps to the housing, causing the angled surface of the shoulder to come into contact with the slips, pushing them to contact the casing to anchorsleeve 600 tocasing 606.Slips 602 may be self-energized and provide a pressure barrier betweenmain housing 603 ofsleeve 600, containing the electronics and explosives, and the exterior wellbore. -
FIGS. 7A-7E are cutaway views of temperature responsive perforatingsleeves 700 illustrating exemplary electronics and explosives configurations. The mechanical design of perforatingsleeves 700 may be constructed according to any of the various embodiments described above with respect toFIGS. 3-6 . In other words, any of the foregoing mechanical configurations may be used in any combination with any of the following electronics and explosives configurations.FIG. 7A illustrates a perforatingsleeve 700 with a unidirectional shapedcharge 701.FIG. 7B illustrates a perforatingsleeve 700 with a bidirectional shapedcharge 702.FIG. 7C illustrates a perforatingsleeve 700 with a unidirectional shaped charge 703 (facing away from the casing) in conjunction with aburst disk 708 disposed on the casing. InFIG. 7D , a cutaway view illustrates a perforating sleeve with a unidirectional shapedcharge 711 facing inward to the casing with aburst disk 712 integral to the exterior wall of thesleeve 700 and aligned with the shaped charge.FIG. 7E illustrates the same charge and burst disk configuration asFIG. 7D , but the view exterior to the sleeve is shown without cutaway. - In each embodiment,
batteries 704 provide power to acontroller 709 that monitors and records the temperature ofcasing 710 via atemperature sensor 705.Controller 709 may be formed from various combinations of integrated or discrete circuitry such as microcontrollers, microprocessors, digital signal processors and the like. Whencontroller 709 detects the predetermined sequence of temperature changes for a given perforating sleeve, a trigger signal may be provided to detonate a primary explosive 706 (e.g., a detonator connected to detonation cord) that may in turn set off the secondary explosive, i.e., shapedcharge 701/702/703/704. Additional circuitry may be provided as required. For example, capacitors may be provided that are charged by the trigger signal to initiate the explosion. Furthermore, in some embodiments, a single explosive, rather than a primary and secondary explosive may be used. The shaped charges may be mounted within the temperature responsive perforating sleeve's main chamber. Additionally, the charges may be embedded into the exterior of the casing and placed at an angle to decrease the overall profile of the perforating sleeve. In some embodiments, a 90 degree configuration and/or a non-cylindrical shaped charge may be used to achieve the desired exterior size and/or profile. - The secondary explosive (e.g., shaped charge) may be arranged such that on detonation it opens a hole through the casing, thereby providing fluid communication from the interior of the casing to the formation.
FIGS. 8A-8D show an enlarged view of the four basic explosive configurations described above with respect toFIGS. 7A-7E .FIG. 8A illustrates aburst disk 802 disposed on the casing that may be used in conjunction with a shapedcharge 803 as was described above with reference toFIG. 7C . When shapedcharge 803 detonates outwardly through the exterior wall of the shell and into the surrounding cement and formation (not shown),burst disk 802 is destroyed, providing the fluid communication path between the interior of the casing and the wellbore/formation.FIG. 8B illustrates a bidirectional shapedcharge 804 as was described above with respect toFIG. 7B . Bidirectional shaped charge shoots both inward throughcasing 801 and outward into the formation to establish he fluid communication path between the interior of the casing and the wellbore/formation.FIG. 8C displays multiple shapedcharges casing 801 and outward (805 b) to establish communication with the formation (not shown).FIG. 8D displays aburst disk 808 integral to the exterior wall of the sleeve's shell 807 (not pictured in 8A-8C). In 8D, the shapedcharge 806 is pointed inward towards thecasing 801. - Additionally, although embodiments showing shaped charges have been described herein, the devices described herein may alternatively or additionally use incendiary materials, “chemical cutters,” or a combination of both to create a pathway for fracture fluid to flow from the casing to the formation. An incendiary based device may use a fuel or propellant to generate heat and pressure, creating holes in the casing for fracturing fluid flow. Incendiary materials may deflagrate as opposed to detonating. A chemical cutter based device may use an explosive charge and/or high pressure jets containing corrosive material to perforate the casing, which may be heated in the process. Bromine Trifluoride is commonly used as a reactive ingredient of a chemical cutter.
- An alternative perforating sleeve design is illustrated in
FIGS. 9A and 9B . The alternative perforating sleeve design may use a temperature actuated trigger protocol as described above, but instead of using explosives to directly penetrate the casing and formation, explosives may be used to create a pressure imbalance to shift open a port.FIGS. 9A and 9B show a top view of a perforatingsleeve 900.FIG. 9A illustrates perforatingsleeve 900 withport 901 in the closed position.FIG. 9B illustrates perforatingsleeve 901 in the open position. In both cases, the perforatingsleeve 900 is shown affixed to/embedded within a casing joint 902, as described further below with respect toFIGS. 9C and 9D . -
FIGS. 9C and 9D illustrate side views of perforatingsleeve 901 sleeve embedded in thecasing 902. Casing 902 may have a recess formed therein for receiving thesleeve 900. At least a portion 903 may penetrate the casing entirely, formingport 904.Perforating sleeve 900 may include ahousing 905 disposed within the recess and secured to the casing by fasteners 906 (e.g., screws, bolts, etc.) Disposed within the housing may be apiston 907, having aport 908 machined therethrough. In the initial, run-in position,piston 907 may be located within the housing so thatport 904 is blocked, preventing fluid communication between the interior and exterior of the casing. In the actuated position (described in greater detail below, the piston may be shifted so thatpiston port 908 aligns with casingport 904, permitting fluid communication between the interior and exterior of the casing. - Also contained within
housing 905 is explosive 909. Explosive 909 may be connected to acontroller 910, which may be powered bybattery 911.Controller 910 may be a controller as described above, i.e., discrete components or an integrated microcontroller, microprocessor, or the like.Controller 910 may trigger explosive 909 in response to temperature changes as described above. Once explosive 909 is triggered, pressure can forcepiston 907 into the open position, in whichpiston port 908 aligns with casingport 904, allowing fluid communication between the casing interior and the wellbore. Excess pressure resulting from the explosion may be discharged throughport 912.Port 912 may initially be blocked by piston 907 (indicated inFIG. 9C ) and opened bypiston 907 moving past the port. Alternatively, an additional port (not shown) may be formed inpiston 907 that aligns withport 912 when the perforating sleeve is in the open position. - Still another alternative sleeve design is illustrated in
FIGS. 10A and 10B .FIG. 10A shows the unbalanced piston design in the closed position, andFIG. 10B shows the unbalanced piston design in the open position. With reference toFIG. 10A , the construction is in general similar to the sleeve described above with respect toFIGS. 9A-9D . More specifically, a recess is formed incasing 1002 into which perforatingsleeve 1000 is positioned.Perforating sleeve 1000 includes ahousing 1005 that is secured tocasing 1002 byfasteners 1006. Withinhousing 1005 is apiston 1007 having aport 1008 formed therethrough. In the closed position, thepiston port 1008 is not aligned withcasing port 1004. - Explosive 1009 may be triggered by a
controller 1010, which is powered bybattery 1011. The controller may operate in response to temperature as described above. When explosive 1009 is triggered, it may open a hole inhousing 1005 allowingwellbore fluid 1012 to enter the recess. This exposure to wellbore pressure may displace piston 1007 (to the left as illustrated) aligningpiston port 1008 withcasing port 1004, thereby opening the sleeve. It will be appreciated thatpiston face 1013 must have a greater area thanpiston face 1014 to ensure that the piston is unbalanced and that unequal forces are acting to move the position to the open position. -
FIGS. 11A-11C depict the mechanics of the shiftingsleeves individual subassembly 1103 with abox thread 1101 for receiving casing joint pin threads, and pinthreads 1102 for threading into a box thread of another casing joint.FIG. 11A illustrates the sleeve in the closed position.FIG. 11B shows the sleeve starting to open.FIG. 11C illustrates the sleeve fully opened with fluid communicating exterior to the sleeve. -
FIGS. 12A and 12B show a side cutaway view of the sleeve mechanics previously described inFIGS. 9C and 9D (with like reference numbers) that have been adapted to be actuated as part ofsubassembly 1103. -
FIGS. 13A and 13B illustrate a side cutaway view of the sleeve mechanics previously described inFIGS. 10A and 10B (with like reference numbers) adapted to be actuated as part of threadedsubassembly 1303. - Remote Isolation Mechanism
- As described above, it may be desirable to provide an isolation mechanism between stages during fracturing operations. Conventionally this has been done with various mechanisms, including progressively sized balls landing on correspondingly sized ball seats deployed within the well. Such conventional arrangements may be used with the perforating sleeve designs described above. Alternatively, fracturing operations efficiency may be improved by providing a remote isolation mechanism that includes a temperature responsive ball seat as described below with reference to
FIGS. 14A and 14B . -
FIG. 14A illustrates aremote isolation mechanism 1400 in the retracted position.FIG. 14B illustratesremote isolation mechanism 1400 in the shifted position.Remote isolation mechanism 1400 may be constructed generally similarly to the sleeve described above with respect toFIGS. 9A-10B and 13A-13B . More specifically, acasing 1400 can have a recess formed therein for receivingremote isolation mechanism 1400 or the shifting mechanism can be built into a threaded subassembly.Remote isolation mechanism 1400 can include ahousing 1405 secured tocasing 1401 withfasteners 1406. Within housing may be apiston 1407.Piston 1407 may be an unbalanced piston that is triggered bycontroller 1410. More specifically, a power supply 1411 (e.g., a battery) may provide power to acontroller 1410, which may be a discrete circuit of logic components, a microcontroller, a microprocessor, or other suitable control device. In some embodiments,controller 1410 may respond to a temperature sensor (not shown) and may be programmed to operate as described above with respect toFIG. 2 . -
Controller 1410 may be configured to trigger an explosive 1409, which may be configured to open a port 1413 (FIG. 14B ) inhousing 1405. This can allow well bore pressure 1414 to act onunbalanced piston 1407, shiftingpiston 1407, which in turn shiftscollapsible ball seat 1412 into the ID of the casing. This can allow an object dropped or pumped down from the surface to land oncollapsible seat 1412 and form a pressure seal between hydraulic fracturing stages. -
FIGS. 14C and 14D illustrate sectional views ofremote isolation mechanism 1400 disposed in awellbore 1415.FIG. 14C showsremote isolation mechanism 1400 in the retracted position, andFIG. 14D showsremote isolation mechanism 1400 in the extended position. In the retracted position, the full diameter ofcasing 1401 is unobstructed. Thus, the wellbore is not restricted whenremote isolation mechanism 1400 is run in-hole or during cementing operations. Whenremote isolation mechanism 1400 is triggered (for example by seeing the same temperature cycling as the perforating sleeves described above),seat 1412 moves into the wellbore to allow a dropped or pumped down object, such as a dart or ball, to form a pressure seal. -
FIGS. 15A-15F illustrates a completion sequence using two, singlecluster perforating sleeves remote isolation mechanisms sleeves remote isolation mechanisms perforating mechanism 1505.Perforating mechanism 1505 may be a perforating sleeve as described herein or may be another mechanism, such as a sliding sleeve, a perforated casing section, etc. Isolation for this first frac stage may be by a conventional isolation mechanism or the remote isolation mechanism described above, neither of which is shown inFIGS. 15A-15F . - As will be appreciated, once the wellbore assembly is run into the well, it will come to thermal equilibrium at a temperature substantially corresponding to the wellbore temperature. The pumping of the first frac stage will cause a first temperature cycle as described above with respect to
FIG. 2 . In other words, during pumping of the first frac stage, the wellbore assembly will reach thermal equilibrium at a temperature substantially corresponding to the temperature of the frac water. When the first frac stage is complete, the wellbore assembly will return to a temperature substantially corresponding to the formation temperature. Thus, after the first frac stage is overremote isolation mechanism 1503 may be triggered by the rise in temperature and the predetermined number of cycles.Remote isolation mechanism 1503 may then shift to create a restriction in the well bore for an object 1506 (FIG. 15B ) dropped or pumped down from the surface to seat on 1503. - Once
object 1506 seats (FIG. 15C ), pressure from surface will keep the object on seat, creating a pressure seal between the first stage and the second stage (corresponding to perforatingsleeve 1501 and remote isolation mechanism 1503).Perforating sleeve 1501 may be triggered by the same temperature cycle that triggeredremote isolation mechanism 1503, thus allowing fluid communication between the interior of the casing and the wellbore. The second may thus be fractured (1507) through perforating sleeve 1501 (FIG. 15D ). This fracturing operation will trigger a further temperature cycle that can triggerremote isolation mechanism 1504 and perforatingsleeve 1502. The triggering ofremote isolation mechanism 1504 can provide a landing for dropped/pumped down object 1508 (FIG. 15E ), which establishes pressure isolation for the third frac stage through perforating sleeve 1502 (FIG. 15F ). - Described above are various features and embodiments relating to temperature responsive devices for use in a fracturing a wellbore. Such temperature responsive devices may be used in a variety of applications, but may be particular advantageous when used in conjunction with fracturing operations, particularly simultaneous fracturing operations of multiple wells.
- Additionally, although numerous specific features and various embodiments have been described, it is to be understood that, unless otherwise noted as being mutually exclusive, the various features and embodiments may be combined in any of the various permutations in a particular implementation. Thus, the various embodiments described above are provided by way of illustration only and should not be constructed to limit the scope of the disclosure. Various modifications and changes can be made to the principles and embodiments herein without departing from the scope of the disclosure and without departing from the scope of the claims.
Claims (24)
1. A temperature responsive completion device, the temperature responsive device comprising:
an explosive; and
a trigger circuit configured to trigger the explosive responsive to a downhole temperature and at least one of a number of temperature cycles and a time period above or below a temperature threshold.
2. The temperature responsive completion device of claim 1 wherein the temperature responsive device is a perforating sleeve adapted to be installed over a casing joint.
3. The temperature responsive completion device of claim 2 wherein the perforating sleeve is configured to be secured to the casing by welding.
4. The temperature responsive completion device of claim 2 wherein the perforating sleeve is configured to be secured to the casing by slips.
5. The temperature responsive completion device of claim 2 wherein the perforating sleeve is configured to be secured to the casing by mechanical fasteners.
6. The temperature responsive completion device of claim 5 wherein the perforating sleeve is located with respect to the casing by one or more pre-drilled holes in the casing.
7. The temperature responsive completion device of claim 1 wherein the temperature responsive device is a sub adapted to be threaded between two casing joints.
8. The temperature responsive completion device of claim 1 wherein the temperature responsive device is a remote isolation mechanism.
9. The temperature responsive completion device of claim 8 wherein the isolation mechanism detonates an explosive to allow wellbore pressure to act on an unbalanced piston.
10. The temperature responsive completion device of claim 8 wherein the isolation mechanism creates a pressure imbalance to shift a sleeve or port.
11. The temperature responsive completion device of claim 8 wherein the isolation mechanism creates a ball seat.
12. The temperature responsive completion device of claim 1 wherein the temperature responsive device is a located at a toe of the well, and wherein the trigger circuit is configured to trigger the explosive responsive to a downhole temperature above a predetermined temperature threshold for a predetermined time period.
13. The temperature responsive completion device of claim 1 wherein the trigger circuit comprises a temperature sensor, a controller, and a plurality of capacitors.
14. The temperature responsive completion device of claim 1 wherein the explosive is a shaped charge.
15. The temperature responsive completion device of claim 14 wherein the shaped charge is a unidirectional shaped charge.
16. The temperature responsive completion device of claim 14 wherein the shaped charge is a bidirectional shaped charge.
17. The temperature responsive completion device of claim 14 wherein the shaped charge ruptures a burst disk.
18. A wellbore assembly comprising:
a casing string;
one or more means for establishing fluid communication between an interior of the casing string and an exterior of the casing string, the one or more means for establishing fluid communication being responsive to a downhole temperature and at least one of a number of temperature cycles and a time period above or below a temperature threshold.
19. The wellbore assembly of claim 18 wherein the one or more means for establishing fluid communication include a perforating sleeve adapted to be installed over a casing joint.
20. The wellbore assembly of claim 18 wherein the one or more means for establishing fluid communication include a sub adapted to be threaded between two casing joints.
21. The wellbore assembly of claim 18 wherein the one or more means for establishing fluid communication include a remote isolation mechanism.
22. The wellbore assembly of claim 18 wherein the one or more means for establishing fluid communication include a device located at a toe of the well, and wherein the trigger circuit is configured to trigger the explosive responsive to a downhole temperature above a predetermined temperature threshold for a predetermined time period.
23. The wellbore assembly of claim 18 wherein the one or more means for establishing fluid communication between an interior of the casing string and an exterior of the casing string comprises an explosive.
24. The wellbore assembly of claim 18 wherein the one or more means for establishing fluid communication between an interior of the casing string and an exterior of the casing string comprises a thermal, incendiary, or chemical cutting device.
Priority Applications (3)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US16/261,687 US20190345802A1 (en) | 2018-05-09 | 2019-01-30 | Temperature Responsive Fracturing |
PCT/US2019/030883 WO2019217301A1 (en) | 2018-05-09 | 2019-05-06 | Temperature responsive fracturing |
CA3099350A CA3099350C (en) | 2018-05-09 | 2019-05-06 | Temperature responsive fracturing |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US201862668859P | 2018-05-09 | 2018-05-09 | |
US16/261,687 US20190345802A1 (en) | 2018-05-09 | 2019-01-30 | Temperature Responsive Fracturing |
Publications (1)
Publication Number | Publication Date |
---|---|
US20190345802A1 true US20190345802A1 (en) | 2019-11-14 |
Family
ID=68463491
Family Applications (2)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US16/261,685 Active US11111763B2 (en) | 2018-05-09 | 2019-01-30 | Temperature responsive fracturing |
US16/261,687 Abandoned US20190345802A1 (en) | 2018-05-09 | 2019-01-30 | Temperature Responsive Fracturing |
Family Applications Before (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US16/261,685 Active US11111763B2 (en) | 2018-05-09 | 2019-01-30 | Temperature responsive fracturing |
Country Status (3)
Country | Link |
---|---|
US (2) | US11111763B2 (en) |
CA (1) | CA3099350C (en) |
WO (1) | WO2019217301A1 (en) |
Cited By (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20210388691A1 (en) * | 2020-06-11 | 2021-12-16 | Halliburton Energy Services,Inc. | Fluid communication method for hydraulic fracturing |
WO2023224637A1 (en) * | 2022-05-16 | 2023-11-23 | Halliburton Energy Services, Inc. | Wireless flow control devices and methods to reestablish fluid flow through a flow control device |
Families Citing this family (4)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
WO2019169490A1 (en) * | 2018-03-05 | 2019-09-12 | Kobold Corporation | Thermal expansion actuation system for sleeve shifting |
US11867033B2 (en) | 2020-09-01 | 2024-01-09 | Mousa D. Alkhalidi | Casing deployed well completion systems and methods |
CN112610198B (en) * | 2020-12-17 | 2022-02-25 | 中国矿业大学 | Coal seam mechanical fracturing and hydraulic drive cooperative targeting fracturing device and method |
US11976550B1 (en) | 2022-11-10 | 2024-05-07 | Halliburton Energy Services, Inc. | Calorimetric control of downhole tools |
Family Cites Families (17)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US2712455A (en) | 1952-10-02 | 1955-07-05 | Nat Supply Co | Pressure actuated seal with relief means |
US3880236A (en) * | 1972-08-09 | 1975-04-29 | Union Oil Co | Method and apparatus for transporting hot fluids through a well traversing a permafrost zone |
US4511374A (en) * | 1984-02-17 | 1985-04-16 | Heath Rodney T | Gas temperature control system for natural gas separator |
US4832121A (en) * | 1987-10-01 | 1989-05-23 | The Trustees Of Columbia University In The City Of New York | Methods for monitoring temperature-vs-depth characteristics in a borehole during and after hydraulic fracture treatments |
US5159145A (en) | 1991-08-27 | 1992-10-27 | James V. Carisella | Methods and apparatus for disarming and arming well bore explosive tools |
US6053111A (en) | 1996-07-23 | 2000-04-25 | Halliburton Energy Services, Inc. | Surface safe rig environment detonator |
US6962202B2 (en) | 2003-01-09 | 2005-11-08 | Shell Oil Company | Casing conveyed well perforating apparatus and method |
US7273102B2 (en) | 2004-05-28 | 2007-09-25 | Schlumberger Technology Corporation | Remotely actuating a casing conveyed tool |
US20080134922A1 (en) | 2006-12-06 | 2008-06-12 | Grattan Antony F | Thermally Activated Well Perforating Safety System |
US20090205826A1 (en) * | 2008-02-19 | 2009-08-20 | Alejandro Rodriguez | Method for Increasing the Fluid Productivity of a Hydraulically Fractured Well |
US8397741B2 (en) | 2009-06-10 | 2013-03-19 | Baker Hughes Incorporated | Delay activated valve and method |
US9249650B2 (en) * | 2010-12-15 | 2016-02-02 | Wallace Bruce | Clean solar energy to enhance oil and gas location separator recovery |
US9010442B2 (en) * | 2011-08-29 | 2015-04-21 | Halliburton Energy Services, Inc. | Method of completing a multi-zone fracture stimulation treatment of a wellbore |
EP2914806A4 (en) | 2012-11-05 | 2016-07-13 | Owen Oil Tools L P | Bi-directional shaped charges for perforating a wellbore |
US9284817B2 (en) | 2013-03-14 | 2016-03-15 | Halliburton Energy Services, Inc. | Dual magnetic sensor actuation assembly |
US9404340B2 (en) * | 2013-11-07 | 2016-08-02 | Baker Hughes Incorporated | Frac sleeve system and method for non-sequential downhole operations |
GB201409382D0 (en) | 2014-05-27 | 2014-07-09 | Etg Ltd | Wellbore activation system |
-
2019
- 2019-01-30 US US16/261,685 patent/US11111763B2/en active Active
- 2019-01-30 US US16/261,687 patent/US20190345802A1/en not_active Abandoned
- 2019-05-06 CA CA3099350A patent/CA3099350C/en active Active
- 2019-05-06 WO PCT/US2019/030883 patent/WO2019217301A1/en active Application Filing
Cited By (3)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20210388691A1 (en) * | 2020-06-11 | 2021-12-16 | Halliburton Energy Services,Inc. | Fluid communication method for hydraulic fracturing |
WO2023224637A1 (en) * | 2022-05-16 | 2023-11-23 | Halliburton Energy Services, Inc. | Wireless flow control devices and methods to reestablish fluid flow through a flow control device |
US11952862B2 (en) | 2022-05-16 | 2024-04-09 | Halliburton Energy Services, Inc | Wireless flow control devices and methods to reestablish fluid flow through a flow control device |
Also Published As
Publication number | Publication date |
---|---|
WO2019217301A1 (en) | 2019-11-14 |
US11111763B2 (en) | 2021-09-07 |
US20190345801A1 (en) | 2019-11-14 |
CA3099350A1 (en) | 2019-11-14 |
CA3099350C (en) | 2022-06-14 |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
US11111763B2 (en) | Temperature responsive fracturing | |
US5845712A (en) | Apparatus and associated methods for gravel packing a subterranean well | |
CA2953571C (en) | Methods for multi-zone fracture stimulation of a well | |
US10053969B2 (en) | Using a combination of a perforating gun with an inflatable to complete multiple zones in a single trip | |
US7325616B2 (en) | System and method for completing multiple well intervals | |
US9506333B2 (en) | One trip multi-interval plugging, perforating and fracking method | |
US4830120A (en) | Methods and apparatus for perforating a deviated casing in a subterranean well | |
US7152676B2 (en) | Techniques and systems associated with perforation and the installation of downhole tools | |
US11293737B2 (en) | Detonation system having sealed explosive initiation assembly | |
US9359877B2 (en) | Method and apparatus for single-trip time progressive wellbore treatment | |
US10221661B2 (en) | Pump-through perforating gun combining perforation with other operation | |
WO2017192878A1 (en) | Directly initiated addressable power charge | |
WO2014060293A2 (en) | Sealing apparatus and method | |
EP2576979A1 (en) | Assembly and method for multi-zone fracture stimulation of a reservoir using autonomous tubular units | |
US9540919B2 (en) | Providing a pressure boost while perforating to initiate fracking | |
US20150007994A1 (en) | Open Hole Casing Run Perforating Tool | |
CA3090586C (en) | Detonation system having sealed explosive initiation assembly | |
WO2021113758A1 (en) | Impact resistant material in setting tool | |
US20210293120A1 (en) | Apparatus and method for stimulating a well | |
CA3151264A1 (en) | Detonation system having sealed explosive initiation assembly | |
CA2639294C (en) | Perforating gun assembly | |
US20240151117A1 (en) | Hydraulic fracturing plug | |
WO1998050678A1 (en) | Perforating apparatus and method | |
GB2360805A (en) | Method of well perforation | |
CA2803328A1 (en) | Method and apparatus for single-trip time progressive wellbore treatment |
Legal Events
Date | Code | Title | Description |
---|---|---|---|
STPP | Information on status: patent application and granting procedure in general |
Free format text: NON FINAL ACTION MAILED |
|
STCB | Information on status: application discontinuation |
Free format text: ABANDONED -- FAILURE TO RESPOND TO AN OFFICE ACTION |