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Your digital window into the world of Unispace
Brand, DEIB and Wellness, Global
We're excited to share our new digital home with you…because we designed it with you in mind. Welcome to the new Unispace.com
Our new digital home, developed with you in mind. Here's why we're so excited about our new website.
If you've visited our website before, you might have noticed by now that things look a little different. We're excited to share our new digital home and our refreshed brand with you. It's 2022, the world, and our clients' needs, are evolving rapidly, and we're evolving too. 800 thinkers, creators, innovators, and explorers across 26 countries worldwide who are passionate about people and the world around us. We worked with Ogilvy Australia and Xen to research, design and develop this carefully designed and constructed new digital home over several months, and here are some of the things we'll hope you'll notice...
Deepening our industry specialization beyond office design
We've experienced rapid growth over the past decade, and acquired two new companies in 2021, global experiential design firm Downstream and life sciences engineering firm BioPharma Engineering. The new site tells our story of our deepening specialization in sectors such as life sciences and experiential design, and our growing team of talent.
Visual accessibility – continuing our commitment to Diversity, Equity, Inclusion & Belonging (DEIB)
As a brand focused on making a DEIB impact, designing a website that improved visual accessibility was a must. Through changes to colors, font, and layout, people with visual impairments will now more easily be able to navigate and read content on the site.
People, people, people
Unispace is all about people. Our focus is on designing spaces for our clients that spark brilliance in the people who use them and it's our talent, which makes this happen. While you're here, we hope you'll get a chance to connect with some of the amazing people that are behind our projects.
Global local expertise
We're a global firm with studios in over 50 locations around the world, so it's important we make our website more user-friendly for clients and talent in the markets where we operate. The next phase of the refresh will see more multi-lingual content, language translation functionality and local features added to the site.
Christian Moore, Senior Designer, Ogilvy says:
"With the new website we wanted to push and extend the Unispace brand into a new space, that reflects their evolving business and story.
We have focused on elevating the whole customer experience, from when customers first visit the website, to comfortably and confidently communicate their story at a first impression. The brand is showcased in the best possible light, in harmony with the services that Unispace offer.
And there's no better way for a company to communicate that it's a diverse and inclusive organization than ensuring that all who may access its services can do so with the least possible amount of resistance."
We hope you like our new window to the world as much as we do.
Chat to us about our approach to creating spaces that bring out the best out of people, get in-touch here.
Welcoming our new Principal of Strategy, Ian Worthy
Joining the team amid the COVID-19 pandemic has given...
Welcoming Jacob Kent as Head of Business Development, Americas
Introducing Jacob Kent, a strategic leader and the new...
Unispace Team
Meet Marianne Weiss, our new Principal of Design
Marianne Weiss, an award-winning creator, comes to...


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Ole Miss football to lose Gregory, Battle
byJoshua Clayton
Ole Miss head coach Matt Luke confirmed on Wednesday that Demarcus Gregory and Miles Battle are no longer practicing with the team and will likely enter the transfer portal.
Luke said the two redshirt freshman wide receivers have expressed concerns about limited playing time during the season and have both decided to leave the program.
"I do not know if they have officially entered the portal," Luke said. "I have talked to both of them about playing time, and it is likely that they will enter the portal. Again, it comes down to playing time. They are both good kids, and I wish them the best."
Gregory has caught six passes for 127 yards this year, and Battle has only two catches for 20 yards. Gregory and Battle are the second and third players to leave the program after quarterback Grant Tisdale entered the transfer portal two weeks ago.
The Ole Miss offense, led by coordinator Rich Rodriguez, has been one-dimensional since the injury of Matt Corral against California. John Rhys Plumlee took over the starting position in a two-quarterback system and has been more of a threat running the ball while Corral, the better passer of the two, stays on the sideline. Since then, the Rebels have struggled to get the ball to their receivers with only five passing touchdowns in six games.
With Plumlee continuing to get the most of the snaps for Ole Miss this season, the run-heavy scheme could lead to more transfers on the offensive side of the ball.

redpajama_set_name: RedPajamaCommonCrawl


I'd fallen in love with a woman but she broke up with me and I was devastated. Six months later, I went into a suicidal depression from the break-up of the relationship, but I resolved to not do what my friends had done. And so I reached out for help.
I feel like I'm climbing as well, if not better, than ever.
Judging by my degradation in the last 24 hours, I'll be surprised if I make it to Tuesday.
I limited myself to one shout a day. But I didn't like the sound of my voice. It sounded panicked, it sounded scared. And I knew from experience you can't hear more than 50 yards either way down a canyon.
I kind of entered a flow state. I've been there before while climbing. You are not thinking ahead. You are just thinking about what is in front of you each second.
I was accustomed to being in far, far riskier environments. So I thought going into that canyon was a walk in the park – there were no avalanches, it was a beautiful day and I was essentially just walking.
And that's where I'm finally at today – my life is about being with my family. This is what's important.
When I climb a fourteener, a 14,000-foot/4,260-meter peak, in the winter by myself, I leave an itinerary and information about where my vehicle will be parked and the name of the county sheriff to contact in case I don't get home.
If you want someone to show up and help you if something bad happens, you'd better tell someone where you're going. And of course I wanted someone to know – but I'd made a choice and it was a choice I was going to have to live with.
What you're looking at there is my arm, going into the rock… and there it is – stuck. It's been without circulation for 24 hours. It's pretty well gone.


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ARMO Biosciences (ARMO) – SanaCurrents Case Study
By Bill Langbein|2020-04-23T10:19:50-04:00August 25th, 2018|Tags: ARMO, Bill Langbein|
ARMO Biosciences (ARMO) listed in January 2018 at $17 per share. The company had a phase III pancreatic cancer drug in AMO010, a recombinant form of human interleukin 10 (IL-10). There is no effective drug to treat pancreatic cancer.
AMO010 demonstrated the ability to activate anti-tumor CD8+ T cells in early clinical trials, an important action for cancer immunotherapies now in development at many drug companies. The company also was testing AMO010 in pancreatic cancer, one of the most aggressive forms of cancer. In a trial of 21 patients with advanced pancreatic cancer, ARMO said no tumor growth was observed in 74% of the patients and 43% experienced prolong survival. The impressive results pointed to a successful outcome of the phase III trial in the fourth quarter of 2018.
ARMO shares rose as high as 50 in the first two months after it listed, partly because of the near term, late-stage trial results and also rumors that a buyer for ARMO could be looming. ARMO CEO Peter Van Vlasselaer had been part of several management teams at companies that were previously sold, most recently at True North Pharmaceuticals, which was purchased by Bioverative [BIVV] in May 2017.
SanaCurrents forecast a successful outcome for the phase III trial on April 13, 2018, when the stock was at 28.94. Eli Lilly agreed to purchase ARMO at $50 per share on May 10, reflecting a 72% return in less than one month.
What exactly did this mean for investors in ARMO shares? In less than 1 month, they netted at least $7,200 on a $10,000 investment after SanaCurrents' initial forecast.
Get SanaCurrents Biotech Sentiment Reports


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US9751767B2 - Catalytic reactor for converting contaminants in a displacement fluid and generating energy - Google Patents
Catalytic reactor for converting contaminants in a displacement fluid and generating energy Download PDF
recycle stream
Eric Prim
Pilot Energy Solutions LLC
2013-10-02 Priority to US201361885872P priority Critical
2014-10-02 Application filed by Pilot Energy Solutions LLC filed Critical Pilot Energy Solutions LLC
2017-01-26 Assigned to PILOT ENERGY SOLUTIONS, LLC reassignment PILOT ENERGY SOLUTIONS, LLC ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: PRIM, ERIC
C01B31/20—
C01B32/50—Carbon dioxide
B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
B01J—CHEMICAL OR PHYSICAL PROCESSES, e.g. CATALYSIS OR COLLOID CHEMISTRY; THEIR RELEVANT APPARATUS
B01J8/00—Chemical or physical processes in general, conducted in the presence of fluids and solid particles; Apparatus for such processes
B01J8/02—Chemical or physical processes in general, conducted in the presence of fluids and solid particles; Apparatus for such processes with stationary particles, e.g. in fixed beds
B01J8/0242—Chemical or physical processes in general, conducted in the presence of fluids and solid particles; Apparatus for such processes with stationary particles, e.g. in fixed beds the fluid flow within the bed being predominantly vertical
B01J8/025—Chemical or physical processes in general, conducted in the presence of fluids and solid particles; Apparatus for such processes with stationary particles, e.g. in fixed beds the fluid flow within the bed being predominantly vertical in a cylindrical shaped bed
B01J8/0285—Heating or cooling the reactor
B01J8/04—Chemical or physical processes in general, conducted in the presence of fluids and solid particles; Apparatus for such processes with stationary particles, e.g. in fixed beds the fluid passing successively through two or more beds
B01J8/0446—Chemical or physical processes in general, conducted in the presence of fluids and solid particles; Apparatus for such processes with stationary particles, e.g. in fixed beds the fluid passing successively through two or more beds the flow within the beds being predominantly vertical
B01J8/0449—Chemical or physical processes in general, conducted in the presence of fluids and solid particles; Apparatus for such processes with stationary particles, e.g. in fixed beds the fluid passing successively through two or more beds the flow within the beds being predominantly vertical in two or more cylindrical beds
B01J8/0457—Chemical or physical processes in general, conducted in the presence of fluids and solid particles; Apparatus for such processes with stationary particles, e.g. in fixed beds the fluid passing successively through two or more beds the flow within the beds being predominantly vertical in two or more cylindrical beds the beds being placed in separate reactors
B01J8/06—Chemical or physical processes in general, conducted in the presence of fluids and solid particles; Apparatus for such processes with stationary particles, e.g. in fixed beds in tube reactors; the solid particles being arranged in tubes
B01J8/065—Feeding reactive fluids
B01J8/067—Heating or cooling the reactor
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
E21B43/164—Injecting CO2 or carbonated water
E21B43/24—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
E21B43/2406—Steam assisted gravity drainage [SAGD]
E21B43/34—Arrangements for separating materials produced by the well
E21B43/40—Separation associated with re-injection of separated materials
B01J2208/00—Processes carried out in the presence of solid particles; Reactors therefor
B01J2208/00008—Controlling the process
B01J2208/00017—Controlling the temperature
B01J2208/00106—Controlling the temperature by indirect heat exchange
B01J2208/00168—Controlling the temperature by indirect heat exchange with heat exchange elements outside the bed of solid particles
B01J2208/00176—Controlling the temperature by indirect heat exchange with heat exchange elements outside the bed of solid particles outside the reactor
B01J2208/00796—Details of the reactor or of the particulate material
B01J2208/00823—Mixing elements
B01J2208/00831—Stationary elements
B01J2208/00849—Stationary elements outside the bed, e.g. baffles
B01J2208/00893—Feeding means for the reactants
B01J2208/00902—Nozzle-type feeding elements
B01J2208/00929—Provided with baffles
B01J2208/00938—Flow distribution elements
B01J2208/02—Processes carried out in the presence of solid particles; Reactors therefor with stationary particles
B01J2208/023—Details
B01J2208/024—Particulate material
B01J2208/025—Two or more types of catalyst
B01J2208/06—Details of tube reactors containing solid particles
B01J2208/065—Heating or cooling the reactor
B01J8/0278—Feeding reactive fluids
F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
F25J2240/00—Processes or apparatus involving steps for expanding of process streams
F25J2240/70—Steam turbine, e.g. used in a Rankine cycle
F25J2240/80—Hot exhaust gas turbine combustion engine
F25J2240/82—Hot exhaust gas turbine combustion engine with waste heat recovery, e.g. in a combined cycle, i.e. for generating steam used in a Rankine cycle
Y02P—CLIMATE CHANGE MITIGATION TECHNOLOGIES IN THE PRODUCTION OR PROCESSING OF GOODS
Y02P90/00—Enabling technologies with a potential contribution to greenhouse gas [GHG] emissions mitigation
Y02P90/02—Total factory control, e.g. smart factories, flexible manufacturing systems [FMS] or integrated manufacturing systems [IMS]
Y02P90/14—Total factory control, e.g. smart factories, flexible manufacturing systems [FMS] or integrated manufacturing systems [IMS] characterised by fault tolerance, reliability of production system
Y02P90/70—Combining sequestration of CO2 and exploitation of hydrocarbons by injecting CO2 or carbonated water in oil wells
A method comprises receiving a carbon dioxide recycle stream having carbon dioxide and hydrocarbons. The carbon dioxide recycle stream is fed to a catalytic reactor. The hydrocarbons are converted to carbon dioxide in the catalytic reactor by a catalytic reaction without combustion to form a purified carbon dioxide recycle stream. Electrical energy is generated by using heat produced by the catalytic reactor in the conversion. Another method comprises receiving a recycle stream having carbon dioxide, C1-C2 hydrocarbons, and C3+ hydrocarbons. The C3+ hydrocarbons are separated from the carbon dioxide and the C1-C2 hydrocarbons. The carbon dioxide and the C1-C2 hydrocarbons are fed to a catalytic reactor at a pressure greater than about 300 pounds per square inch (psi), and the C1-C2 hydrocarbons are converted to carbon dioxide, water, and heat.
CROSS-REFERENCE TO RELATED APPLICATION
The present application claims priority to U.S. Provisional Patent Application No. 61/885,872, filed on Oct. 2, 2013 by Eric Prim, and entitled "Catalytic Reactor for Converting Contaminants in a Displacement Fluid and Generating Energy," which is incorporated herein by reference.
STATEMENT REGARDING FEDERALLY SPONSORED RESEARCH OR DEVELOPMENT
REFERENCE TO A MICROFICHE APPENDIX
Enhanced recovery methods are commonly used to increase the amount of hydrocarbons that can be recovered from a reservoir. One enhanced recovery method includes a miscible displacement process. In a miscible displacement process, a displacement fluid (e.g., carbon dioxide with light hydrocarbons) is selected that is miscible with the hydrocarbons to be recovered from the reservoir. The displacement fluid is injected into the reservoir (e.g., through an injection well) and forms a miscible solution with the hydrocarbons. Additional displacement fluid is injected into the reservoir to drive the miscible solution with the hydrocarbons out of the reservoir (e.g., through a recovery well).
Two important parameters in a miscible displacement process include the minimum miscible pressure and the fracture pressure. The minimum miscible pressure is the lowest pressure at which the displacement fluid and the hydrocarbons can become a miscible solution. The fracture pressure is the pressure at which damage (e.g., structural damage) of the reservoir may occur. Accordingly, to use a particular miscible displacement process at a particular reservoir, the minimum miscible pressure should be lower than the fracture pressure. This enables the miscible solution to be formed and driven from the reservoir without damaging the reservoir. Additionally, it may be preferable to operate a miscible displacement process at a pressure above the minimum miscible pressure to prevent low miscibility, unstable displacements, fingerings, and poor recovery. Therefore, it may be desirable to lower a minimum miscible pressure of a displacement fluid.
In one aspect, the disclosure includes a method comprising receiving a carbon dioxide recycle stream having carbon dioxide and hydrocarbons. The carbon dioxide recycle stream is fed to a catalytic reactor. The hydrocarbons are converted to carbon dioxide in the catalytic reactor by a catalytic reaction without combustion to form a purified carbon dioxide recycle stream. Electrical energy is generated by using heat produced by the catalytic reactor in the conversion.
In another aspect, the disclosure includes a method comprising receiving a recycle stream that comprises carbon dioxide, C1-C2 hydrocarbons, and C3+ hydrocarbons. The C3+ hydrocarbons are separated from the carbon dioxide and the C1-C2 hydrocarbons. The carbon dioxide and the C1-C2 hydrocarbons are fed to a catalytic reactor at a pressure greater than about 300 pounds per square inch (psi), and in embodiments, as high as 700 psi, and the C1-C2 hydrocarbons are converted to carbon dioxide, water, and heat.
In yet another aspect, a set of process equipment comprises a natural gas liquids (NGL) recovery unit, a catalytic reactor, and a dehydrator. The NGL recover unit is configured to receive a recycle stream and separate the recycle stream into an NGL stream and a carbon dioxide recycle stream, wherein the NGL stream comprises C3+ hydrocarbons, and wherein the carbon dioxide recycle stream comprises carbon dioxide and C1-C2 hydrocarbons. The catalytic reactor is configured to receive the carbon dioxide recycle stream and convert the C1-C2 hydrocarbons in the carbon dioxide recycle stream to carbon dioxide by a catalytic reaction without combustion to produce a purified carbon dioxide recycle stream, and the dehydrator is configured to remove water from the purified carbon dioxide recycle stream and feed the dehydrated purified carbon dioxide recycle stream to a hydrocarbon injection well for use in an enhanced oil recovery operation.
These and other features will be more clearly understood from the following detailed description taken in conjunction with the accompanying drawings and claims.
For a more complete understanding of the disclosure, reference is now made to the following brief description, taken in connection with the accompanying drawings and detailed description, wherein like reference numerals represent like parts.
FIG. 1 is a schematic diagram of a miscible displacement system that uses a catalytic reactor to convert contaminants in a displacement fluid and generate energy.
FIG. 2 is a schematic diagram of a single fixed bed reactor system.
FIG. 3 is a schematic diagram of a two fixed bed reactor system.
FIG. 4 is a schematic diagram of a mixer and distributer that can be used to feed a catalytic reactor.
FIG. 5 is a side view of a catalytic reactor and a boiler.
FIG. 6 is a front view of an array of catalytic reactor tubes.
FIG. 7 is a schematic diagram of a catalytic reactor tube.
FIG. 8 is a block diagram of a catalytic reactor system with a preheater.
It should be understood at the outset that although an illustrative implementation of one or more embodiments are provided below, the disclosed systems and/or methods may be implemented using any number of techniques, whether currently known or in existence. The disclosure should in no way be limited to the illustrative implementations, drawings, and techniques illustrated below, including the exemplary designs and implementations illustrated and described herein, but may be modified within the scope of the appended claims along with their full scope of equivalents.
Embodiments of the present disclosure include a catalytic reactor for converting contaminants in a displacement fluid and generating energy. In one example, for illustration purposes only and not by limitation, a miscible displacement process uses carbon dioxide as the displacement fluid to recover hydrocarbons from a reservoir. When carbon dioxide is used as the displacement fluid, a miscible solution of carbon dioxide and hydrocarbons is recovered from a recovery well. A carbon dioxide recycle stream is then separated from the heavier hydrocarbons (e.g., C3+ or C4+ hydrocarbons). The carbon dioxide recycle stream is then fed to a catalytic reactor to convert contaminants and generate energy. For instance, the carbon dioxide recycle stream may include some C1 to C3 hydrocarbons (e.g., methane, ethane, propane, etc.). In such a case, the catalytic reactor converts the C1 to C3 hydrocarbons into carbon dioxide and produces heat. By converting the C1 to C3 hydrocarbons into carbon dioxide, the resulting carbon dioxide recycle stream contains a greater amount of carbon dioxide and a lower amount of contaminants. This may be beneficial in reducing the minimum miscible pressure of the carbon dioxide recycle stream, which can result in greater hydrocarbon recovery from the reservoir. Additionally, the heat generated by the catalytic reactor can be used to generate steam to operate a generator to produce power. Accordingly, in at least certain situations, embodiments of catalytic reactors of the present disclosure can be advantageous in reducing the minimum miscible pressure of a displacement fluid and generating energy. These and other features and advantageous are described in greater detail below.
FIG. 1 illustrates a miscible displacement system 100 that uses a catalytic reactor 102 to convert contaminants in a displacement fluid and generate energy. System 100 includes a reservoir 104 having one or more injection wells 106 and one or more recovery wells 108. Reservoir 104 may be an underground reservoir that includes hydrocarbons. In an embodiment, a displacement fluid is fed to injection well 106 through a feed line 110. The displacement fluid may comprise one or more of carbon dioxide, air, water, nitrogen, flue gas, hydrocarbons (e.g., methane, ethane, propane, etc.), or any other suitable displacement fluid. The displacement fluid may form a miscible solution with hydrocarbons in reservoir 104 and drives the miscible solution to the recovery well 108. From the recovery well 108, the miscible solution flows through line 111 and is optionally compressed by one or more compressors 112 (e.g., one to four stages of compressors). The compressed miscible fluid is then fed to a natural gas liquids recovery unit 114 though line 113. A portion of the miscible solution (e.g., in the form of the compressed miscible fluid) may optionally bypass the natural gas liquids recovery unit 114 (e.g., via bypass line 148), as is described in more detail below. The natural gas liquids recovery unit 114 optionally removes C3+ or C4+ hydrocarbons (e.g., propane and higher hydrocarbons or butane and higher hydrocarbons, respectively) from the compressed miscible solution to generate a natural gas liquids product 116, which may flow through line 115. For example, the natural gas liquids recovery unit 114 may remove from about 20 mol % to about 80 mol % of the C3 hydrocarbons received from line 113; the natural gas liquids recovery unit 114 may remove from about 80 mol % to about 100 mol % of the C4 hydrocarbons received from line 113; the natural gas liquids recovery unit 114 may remove from about 90 mol % to about 100 mol % of the C5 hydrocarbons received from line 113; or combinations thereof. The removed C3 hydrocarbons, C4 hydrocarbons, C5 hydrocarbons, or combinations thereof which form the natural gas liquids product 116 may flow via line 115 from the natural gas liquids recovery unit 114. In certain situations, the natural gas liquids recovery unit 114 may perform the separation without subjecting the miscible solution to any cryogenic conditions, membranes, or carbon dioxide recovery solvents. Some examples of natural gas liquids recovery units that can be used are described in U.S. Patent Application Publication No. 2013/0333417 A1, filed Jul. 19, 2013, by Eric Prim, et al., and entitled "NGL Recovery Without Cryogenic Conditions, Membranes, and Carbon Dioxide Recovery Solvents," and in U.S. Patent Application Publication No. 2013/0298601 A1, filed on Jul. 19, 2013, by Eric Prim, et al., and entitled "Sour NGL Stream Recovery," both of which are herein incorporated by reference in their entirety. However, embodiments are not limited to any specific implementation of natural gas liquids recovery unit 114 and may include any type of natural gas liquids recovery unit 114. Additionally, in some embodiments, a natural gas liquids recovery unit 114 may not be included. For instance, in some cases, a stream (e.g., line 111, line 113, or both) may be relatively lean with respect to heavier hydrocarbons (e.g., C3+ or C4+ hydrocarbons), and it may not be necessary or economically prudent to remove heavier hydrocarbons (e.g., C3+ or C4+ hydrocarbons) from the stream prior to being fed to an acid gas removal unit 118 or catalytic reactor 102.
Natural gas liquids recovery unit 114 also generates a lean displacement fluid recycle stream (e.g., a carbon dioxide recycle stream) that is output to line 117. The lean displacement fluid recycle stream in line 117 may be at a pressure of about 300 psi or more, about 400 psi or more, about 500 psi or more, about 600 psi or more, about 700 psi or more, or be in a range of about 300 to about 700 psi. In one embodiment, the lean displacement fluid recycle stream in line 117 comprises about 50 molar % or more carbon dioxide. Alternatively, the lean displacement fluid recycle stream in line 117 may comprise about 60 molar % or more carbon dioxide, about 70 molar % or more carbon dioxide, about 80 molar % or more carbon dioxide, about 90 molar % or more carbon dioxide, about 95 molar % or more carbon dioxide, about 97 molar % or more carbon dioxide, or about 99 molar % or more carbon dioxide. It should also be noted that due to the relatively high carbon dioxide concentration of the lean displacement fluid recycle stream and/or the relatively high pressure that the lean displacement fluid stream may not be combustible. Accordingly, embodiments of the present disclosure that use a catalytic reactor (e.g., catalytic reactor 102) can be used in settings where other processes (e.g., combustion processes) cannot be used.
In embodiments, the carbon dioxide recycle stream may comprise one or more acid gases (e.g., hydrogen sulfide). The lean displacement fluid recycle stream flowing from the natural gas liquids recovery unit 114 in line 117 may undergo a sweetening process in an acid gas removal unit 118 to remove all or a portion of any acid gases. The sweetened displacement fluid recycle stream then flows from the acid gas removal unit 118 through line 120 to catalytic reactor 102. A portion of the sweetened displacement fluid recycle stream may optionally bypass the catalytic reactor 102 (e.g., via bypass line 146), as is described in more detail below.
While atmospheric air could be fed into catalytic reactor 102, it is generally preferable to minimize or prevent the introduction of nitrogen gas into system 100 because nitrogen may raise the minimum miscible pressure of the injectable displacement fluid recycle stream (e.g., the displacement fluid that is fed to injection well 106 through feed line 110). System 100 may also comprise an oxygen generator 122. Oxygen generator 122 may receive air (e.g., from the atmosphere, through line 124, or both) and may separate the air into a nitrogen-rich stream (e.g., which flows through line 126) and an oxygen-rich gas (e.g., which flows through line 128). In some cases, the oxygen-rich stream in line 128 may still include some nitrogen. For instance, the oxygen-rich stream in line 128 may comprise about 80 molar % oxygen, about 90 molar % oxygen, about 95 molar % oxygen, about 98 molar percent oxygen, or about 99 molar percent oxygen, with the balance composition being substantially all nitrogen. In a specific example, the oxygen-rich gas in line 128 may comprise about 92 to about 96 molar % oxygen and about 4 to about 8 molar % nitrogen. Although nitrogen can increase a minimum miscible pressure, the amount of nitrogen that is introduced is an order of magnitude less than the amount carbon dioxide produced by converting hydrocarbons to carbon dioxide in the catalytic reactor 102. Accordingly, system 100 may improve the minimum miscible pressure of an injectable displacement fluid recycle stream despite introducing some nitrogen. The separation within the oxygen generator 122 is optionally performed using or without using any cryogenic or other liquification processes. The nitrogen-rich stream may be either released to the atmosphere or captured and retained for some other use, and the oxygen-rich gas may be fed to the catalytic reactor 102 through line 128. However, in another embodiment, system 100 does not need to include an oxygen generator 122. Instead, an alternative source of oxygen (e.g., tanks of oxygen) can be used to provide oxygen for system 100.
Catalytic reactor 102 optionally includes one or more catalysts. Some examples of catalysts include, but are not limited to, catalysts which comprise nickel, iron, noble metals (e.g., palladium, platinum, silver, gold, iridium, osmium, rhodium, ruthenium), etc. The catalysts may be supported on an inorganic support such as silica, alumina, other supports known in the art with the aid of this disclosure, or combinations thereof. Catalytic reactor 102 receives the oxygen-rich gas through line 128 and the sweetened displacement fluid recycle stream through line 120 and uses the one or more catalysts to convert contaminants (e.g., hydrocarbons) received from the sweetened displacement fluid recycle stream line 120 to one or more different chemicals (e.g., carbon dioxide, water, reaction products known to those skilled in the art with the aid of this disclosure, etc.). The different chemicals illustratively improve (e.g., lower) the minimum miscible pressure of the sweetened displacement fluid recycle stream received from line 120. For instance, in an embodiment in which system 100 uses carbon dioxide as the displacement fluid and the sweetened displacement fluid recycle stream in line 120 contains C2− or C3− hydrocarbons as contaminants, catalytic reactor 102 converts the C2− or C3− hydrocarbon contaminants into carbon dioxide, water, and heat. Within catalytic reactor 102, the hydrocarbons and oxygen from the oxygen-rich stream received from line 128 undergo chemical reactions according to the following equations:
CH4+2O2→CO2+2H2O+Heat,
2C2H6+7O2→4CO2+6H2O+Heat, and
C3H8+5O2→3CO2+4H2O+Heat.
The chemical reactions shown above result in a reacted displacement fluid recycle stream emitted from the catalytic reactor 102 in line 130 that may include carbon dioxide, water, and little or none of the hydrocarbons originally present (e.g., less than about 0.1 molar % of the feed hydrocarbons). In embodiments, the catalytic reactor may convert about 80 molar % or more of the hydrocarbons, about 90 molar % or more of the hydrocarbons, about 95 molar % or more of the hydrocarbons, about 98 molar % or more of the hydrocarbons, or about 99 molar % or more of the hydrocarbons to carbon dioxide and water. As such, the reacted displacement fluid recycle stream in line 130 that is output by catalytic reactor 102 contains a greater amount of the displacement fluid (e.g., carbon dioxide) and fewer contaminants (e.g., C2− or C3− hydrocarbons), which lowers the minimum miscible pressure of the reacted displacement fluid recycle stream in line 130.
In certain embodiments, the catalytic reactor 102 converts the contaminants solely through the use of catalytic reactions, and no traditional combustion methods are used in the catalytic reactor 102 (e.g. the catalytic reactor 102 does not contain a burner or other ignition source). For instance, high operating pressures (e.g., about 300 psi or more) and/or high carbon dioxide concentrations (e.g., about 50 molar %, about 60 molar %, about 70 molar %, about 80 molar %, about 90 molar %, about 95 molar %, about 97 molar %, or about 99 molar % or more carbon dioxide) can prevent combustion from being able to occur. Accordingly, the catalytic reactor 102 may be configured to convert the contaminants using only catalytic reactions without traditional combustion methods.
Catalytic reactor 102 may also include a boiler 132. Boiler 132 may receive the heat energy produced by the chemical reaction in catalytic reactor 102. Boiler 132 may use that heat energy to boil water or another heat exchange fluid to produce a steam that is fed to a power generator 136 (e.g., a steam turbine power generator) through line 134 or is used for other purposes. Power generator 136 may use the steam received from line 134 to generate power 138. Power 138 can be used to power system 100 or can be captured and used for other purposes. Additionally, water or other heat exchange fluid condensate produced by the power generator 136 may be returned to boiler 132 via line 140 and reused to generate more steam or other vapor.
In one embodiment, catalytic reactor 102 and boiler 132 may be implemented using a shell and tube heat exchanger with catalysts within the tubes. In such a case, the oxygen-rich gas in line 128 and the sweetened displacement fluid recycle stream in line 120 are fed to the tubes and the contaminants are converted to the other chemicals within the tubes. The heat produced from the conversion is transferred from within the tubes to water or another heat exchange fluid that is contained in the shell side (e.g. between the outside of the tubes and the shell wall). The heat transfer causes the water or other heat exchange fluid to boil to produce steam or vapor.
The reacted displacement fluid recycle stream may flow from the catalytic reactor 102 through line 130 to be processed through a dehydrator 142. Water can be contained in the displacement recycle stream in line 111 as it leaves the recovery well 108 (and thus carried through system 100 as the displacement recycle stream flows therethrough) and/or water may be added to the displacement recycle stream through the chemical reaction(s) that occur in catalytic reactor 102. Dehydrator 142 can remove all or a portion of water contained in the reacted displacement fluid recycle stream of line 130. In one embodiment, dehydrator 142 comprises molecular sieves, a glycol (e.g., diethylene glycol, triethylene glycol, etc.) dehydrator or any other suitable type of dehydrator. In addition to or instead of dehydrator 142, system 100 may also include one or more heat exchangers or other mechanisms to remove water from reacted displacement fluid recycle stream contained in line 130 by cooling the reacted displacement fluid recycle stream from line 130 to condense water. Some or all of the water removed either in a heat exchanger and/or in a dehydrator 142 may be fed back to the boiler 132 (e.g., via line 140 and 143) and can be used to generate steam or can be discarded.
From dehydrator 142, dehydrated displacement fluid recycle stream may flow through line 141 for processing through one or more compressors 144 (e.g., one to two stages of compressors) to generate the injectable displacement fluid recycle stream in feed line 110 having a higher pressure than in bypass line 148 and/or line 141, which is re-injected to the injection well 106. Typical reinjection pressures may be in the range of from about 1,500 psi to about 2,000 psi. Higher injection pressures may improve miscibility. In embodiments having no dehydrator 142, the reacted displacement fluid recycle stream may flow from the catalytic reactor 102 through line 130 for processing through one or more compressors 144 (e.g., one to two stages of compressors) to generate the injectable displacement fluid recycle stream in line 110 having a higher pressure, which is re-injected to the injection well 106.
As described briefly above, system 100 may optionally include one or more bypass lines 146 and/or 148. Bypass line 146 may take a portion of the sweetened displacement fluid recycle stream in line 120 positioned between the natural gas liquids recovery unit 114 and the catalytic reactor 102 and may redirect the portion to a later portion of the process (e.g., upstream of compressors 144). Bypass line 148 may take a portion of the miscible solution in line 113 between the natural gas liquids recovery unit 114 and compressors 112, and may redirect the portion to a later portion of the process (e.g., upstream of compressors 144). Accordingly, bypass lines 146 and/or 148 can be used to control an amount of the miscible solution that is processed by natural gas liquids recovery unit 114 and/or catalytic reactor 102.
FIGS. 2-8 illustrate various alternative for the system 100. Unless otherwise stated, the alternative embodiments use and produce stream compositions having pressures and temperatures similar to those described above.
FIG. 2 illustrates a system 200 that uses a single fixed bed reactor 202 and a separate steam generator 204. The single fixed bed reactor 202 and separate steam generator 204 can be used in addition to, or in place of, the combined catalytic reactor 102 and boiler 132 in FIG. 1.
In system 200, the displacement fluid recycle stream in line 206 (e.g., comprising the sweetened displacement fluid recycle stream in line 120 of FIG. 1 or a reactor effluent from the catalytic rector 102) may be combined with an oxygen-rich stream in line 208 (e.g., the gaseous stream in line 128 of FIG. 1) to yield a combined stream 210 that is fed to fixed bed reactor 202. In alternative embodiments, lines 206 and 208 may feed to the reactor 202 separately. Contaminants in the displacement fluid recycle stream in line 206 undergo a chemical reaction to convert the contaminants to different chemicals (e.g., methane to carbon dioxide and water, etc.). Similar to the system 100 in FIG. 1, system 200 may convert the contaminants solely using catalytic reactions and no combustion occurs within the fixed bed reactor 202. The chemical reactions may also generate heat, which increases the temperature of the reacted displacement fluid recycle stream in line 212 as compared to the input combined stream 210.
The reacted displacement fluid recycle stream may flow in line 212 to a steam generator 204. Steam generator 204 absorbs heat from the reacted displacement fluid recycle stream received via line 212 to generate steam, which is fed to a power generator (e.g., power generator 136 of FIG. 1) via line 214 to produce electric power. Steam generator 204 may be a boiler, heat exchanger, or any other apparatus configured to receive the reacted displacement fluid recycle stream in line 212 and generate steam.
The first cooled displacement fluid recycle stream may flow from the steam generator 204 through line 216 and optionally pass through a heat recovery unit 218, which may further cool the first cooled displacement fluid recycle stream to generate a second cooled displacement fluid recycle stream in line 220. For instance, heat recovery unit 218 may comprise a heat exchanger that receives water stream via line 222. Water stream received from line 222 absorbs some of the heat energy of the first cooled displacement fluid recycle stream received from line 216 in the heat recovery unit 218, and the heated water is returned in line 224 to the steam generator 204 where it can be used to generate steam. In one embodiment, water stream in line 222 may include condensate from a power generator (e.g., power generator 136 of FIG. 1). However, water stream in line 222 is not limited to coming from any particular source. In addition, any suitable heat exchange fluid may be used in the heat recovery unit 218, including water.
After leaving heat recovery unit 218 in line 220, the second cooled displacement fluid recycle stream may undergo any other processing (e.g., dehydration, compression, etc. as discussed for FIG. 1) and then be returned to an injection well where it is used as a displacement fluid.
FIG. 3 illustrates a system 300 that uses two fixed bed reactors 302, 304 and a separate steam generator 306. The two fixed bed reactors 302, 304 and steam generator 306 can be used in addition to, or in place of, the combined catalytic reactor 102 and boiler 132 in FIG. 1 and/or the single fixed bed reactor 202 and steam generator 204 in FIG. 2. Additionally, although the specific example in FIG. 3 shows two fixed bed reactors 302, 304, embodiments are not limited to any particular number of reactors and may include any number of reactors (e.g., 2, 3, 4, 5, etc.). As discussed previously, the chemical reactions that occur within reactors of the present disclosure may generate heat. In certain circumstances, it may be desirable to perform the chemical reactions in multiple steps to limit the amount of heat generated at any particular reactor and/or to optimize the capture of the heat energy.
System 300 optionally includes an oxygen source 308 (e.g., an oxygen generator 122 of FIG. 1, oxygen tanks, etc.). Oxygen may flow from the oxygen source 308 through a first oxygen-rich stream in line 310 (e.g., the gaseous stream in line 128 of FIG. 1) that combines with a displacement fluid stream in line 312 (e.g., sweetened displacement fluid stream of line 120 of FIG. 1) to form a combined stream in line 314 that is fed to the first fixed bed reactor 302. In alternative embodiments, lines 308 and 310 may feed to the reactor 302 separately. A portion of the contaminants in the displacement fluid stream in line 314 may undergo a catalytic chemical reaction to convert the contaminants to different chemicals. The chemical reactions also generate heat that increases the temperature of the first reacted displacement fluid recycle stream in line 316 as compared to the combined stream in line 314.
The first reacted displacement fluid recycle stream flows in line 316 and is fed to a heat exchanger 318. Heat exchanger 318 receives a water stream in line 320 that is used to cool the first reacted displacement fluid recycle stream received from line 316 which emits from the heat exchanger 318 as a first cooled displacement fluid recycle stream in line 322. The water stream in line 320 may be condensate from a power generator (e.g., power generator 136 of FIG. 1) and/or may be water from any other source. After cooling the first reacted displacement fluid recycle stream in the heat exchanger 318, the heated water exits heat exchanger 318 as a heated water stream in line 324. In addition, any suitable heat exchange fluid may be used in the heat exchanger 318, including water.
The first cooled displacement fluid stream in line 322 may be combined with a second oxygen-rich stream in line 326 (e.g., the gaseous stream in line 128 of FIG. 1) from oxygen source 308 to form a combined stream in line 328 that is fed to the second fixed bed reactor 304. A portion of the contaminants that remain in the first cooled displacement fluid stream received from line 322 may undergo catalytic chemical reactions to convert the contaminants to different chemicals in the second fixed bed reactor 304. The chemical reactions generate heat that increases the temperature of the second reacted fluid recycle stream in line 330 as compared to the first cooled displacement fluid recycle stream in line 328.
The second reacted displacement fluid recycle stream flows in line 330 and is fed to a steam generator 306. Steam generator 306 may absorb heat from the second reacted displacement fluid recycle stream received from line 330 to generate steam (e.g., which may emit from the steam generator 306 in line 332), which may be fed to a power generator (e.g., power generator 136 of FIG. 1) to produce electric power. Steam generator 306 may be a boiler, a heat exchanger, or any other apparatus configured to receive a second reacted displacement fluid recycle stream from line 330 and generate steam.
The second cooled displacement fluid recycle stream may flow from the steam generator 306 through line 334 and optionally passes through a second heat exchanger 336. Heat exchanger 336 cools the second cooled displacement fluid recycle stream received from line 334 using the heated water stream received from the first heat exchanger 318 in line 324. Additionally, heat exchanger 336 heats the water stream received from line 324 and outputs a second heated water stream in line 338 that is fed to steam generator 306 and is used to generate steam (e.g., see above for description of the steam generator 306). In addition, any suitable heat exchange fluid may be used in the heat exchanger 336, including water.
After leaving heat exchanger 336 in line 340, the third cooled displacement fluid recycle stream may undergo any other processing (e.g., dehydration in dehydrator 142 of FIG. 1 or in another dehydrator, compression in compressor 144 of FIG. 1 or another compressor, etc.) and then be returned to an injection well (e.g., injection well 106) where it is used as a displacement fluid.
FIG. 4 illustrates a mixer 402 and a distributer 404 that can be used to feed a catalytic reactor 406 (e.g., catalytic reactor 102 of FIG. 1, reactor 202 of FIG. 2, reactor 302 of FIG. 3, reactor 304 of FIG. 3, etc.). An oxygen-rich stream flowing through line 408 (e.g., the gaseous stream in line 128 of FIG. 1) and a displacement fluid recycle stream flowing through line 410 (e.g., line 120 of FIG. 1, line 206 of FIG. 2, line 312 of FIG. 3, line 322 of FIG. 3, etc.) may combine into a combined stream in line 409 (e.g., line 210 of FIG. 2, line 314 of FIG. 3, line 328 of FIG. 3, etc.) that is fed to mixer 402 (e.g., a static mixer) to blend the oxygen and the displacement fluid recycle stream. The blended stream is then output to the catalytic reactor 406 using a static or dynamic distributor 404 (e.g., a vane distributer). The distributor 404 widens a spraying angle of the blended stream such that the blended stream is more evenly distributed across a tube sheet 412 of catalytic reactor 406 (e.g., catalytic reactor 102 of FIG. 1, reactor 202 of FIG. 2, reactor 302 of FIG. 3, or reactor 304 of FIG. 3 may comprise a tube sheet such as tube sheet 412). The blended stream then enters the apertures of reactor tubes 414 that include at least one catalyst. While in the reactor tubes 414, contaminants within the blended stream received from line 409 may undergo chemical reactions to convert the contaminants to different chemicals as described above. The chemical reactions generate heat that increases the temperature of water or other heat exchange fluid known to those skilled in the art with the aid of this disclosure that is included along the outside of reactor tubes 414 to generate steam.
FIG. 5 illustrates a side view of one embodiment of a combined catalytic reactor and boiler 500 (e.g., catalytic reactor 102 and boiler 132 of FIG. 1). The combined reactor and boiler 500 includes an outer shell 502 and one or more tubes 504 within the outer shell 502. Each tube 504 includes one or more catalyst, and a displacement fluid recycle stream enters and exits the tubes 504 through tube sheets 506. For instance, a displacement fluid recycle stream (e.g., from line 120 of FIG. 1, from line 206 or 210 of FIG. 2, from line 312 or 314 of FIG. 3, from line 322 or 328 of FIG. 3, etc.) can be sprayed across one of the tubes sheets 506 as is shown and described for FIG. 4. Within the outer shell 502 and outside of the tubes 504 is a cavity 508 that holds liquid water or other heat exchange fluid. The liquid (e.g., water or other heat exchange fluid) may enter through an entrance port 510. The liquid may come from condensate returned from a power generator. As the contaminants in the displacement fluid recycle stream in tubes 504 undergo chemical reactions which generate heat, the water outside of the tubes in cavity 508 heats up and some of the water boils into vapor (e.g., steam). The vapor exits to a vapor disengagement header 512 through one or more vapor entrance ports 514. From vapor disengagement header 512, vapor exits through one or more vapor exit ports 516 and eventually is fed to a power generator. Additionally, it should be noted that tubes 504 have a length 518. In an embodiment, length 518 may be selected based upon the surface area of tubes 504.
FIG. 6 illustrates a front view of an array of catalytic reactor tubes 600. Array 600 has a height 602 and a width 604. In one embodiment, height 602 and width 604 are both about 48 inches, and array 600 includes tubes having diameters of about 2 inches and the tubes are spaced apart by about 2 inches (e.g., about 4 inches between the tube centers). In another embodiment, height 602 and width 604 are both about 36 inches, and array 600 includes tubes having diameters of about 2 inches and the tubes are spaced apart by about 1 inch (e.g., about 3 inches between the tube centers). However, embodiments are not limited to any number of tubes or dimensions, and embodiments may include any number of tubes having any dimensions. Moreover, a square array 600 is shown in FIG. 6; however, embodiments are not limited to square arrangements and may include, in addition or in the alternative, arrays that are circular, triangular, oval, pentagonal, hexagonal, etc. arrangements. Moreover, the tubes of array 600 are shown as having a circular cross-section; however, embodiments are not limited to circular cross sections and may include in addition or in the alternative cross-sections of other geometries, e.g., square, triangle, oval, pentagon, hexagon, octagon, etc.
FIG. 7 is a perspective view of an embodiment of one catalytic reactor tube 700. Tube 700 may have a screen 702 that forms the outer surface tube 700. In one embodiment, tube 700 has a first portion 704 that contains one or more catalyst and a second portion 706 that does not contain any catalyst. The second portion may be configured such that the heat of the reactor 102 has time to transfer to the water on the other side of the tube 700. Tube 700 illustratively has an overall length 708, the first portion 704 has a length 710, and the second portion has a length 712. In one specific example, for illustration purposes only and not by limitation, overall length 708 is about 25 feet, first portion length 710 is about 20 feet, and second portion length 712 is about 5 feet. However, embodiments of tube 700 are not limited to any particular configuration and dimensions, and embodiments can include configurations and dimensions than the ones shown in FIG. 7.
FIG. 8 is a block diagram of another embodiment of a catalytic reactor system 800. System 800 optionally includes a reactor/boiler 802 (e.g., reactor 102/boiler 132 of FIG. 1), a preheater 804, an air cooler 806, and a dehydrator 808 (e.g., dehydrator 142 of FIG. 1). A displacement fluid recycle stream flowing in line 810 (e.g., line 120 of FIG. 1) and an oxygen-rich steam flowing in line 812 (e.g., the gaseous stream flowing in line 128 of FIG. 1) may enter reactor/boiler 802. Displacement fluid recycle stream in line 810 may include carbon dioxide and hydrocarbons (e.g., methane, ethane, and/or propane). In one particular example, for illustration purposes only and not by limitation, displacement fluid recycle stream flowing in line 810 may include about 92 molar % carbon dioxide and about 8 molar % hydrocarbons. In one embodiment, the reacted displacement fluid recycle stream emitted from the reactor/boiler 802 in line 813 may have a temperature of about 500° Fahrenheit (F).
The heat generated from the chemical reactions in reactor/boiler 802 may be used to boil water or other heat exchange fluid received from line 814 to generate a vapor stream which emits from the reactor/boiler 802 in line 816. Input water stream or other heat exchange fluid in line 814 may be at a temperature of about 190° F., and vapor stream in line 816 may be at a temperature of about 470° F. and have a pressure of about 500 psi to about 700 psi (e.g., about 600 psi).
Preheater 804 may receive the reacted displacement fluid recycle stream emitted from the reactor/boiler 802 in line 813 and use it to preheat an input water (or other heat exchange fluid) stream received from line 818 (e.g., a water stream from condensate from a power generator). The input water or other heat exchange fluid stream in line 818 may have a temperature of about 100° F., and as previously mentioned, the resulting heated water or other heat exchange fluid stream flowing in line 814 may have a temperature of about 190° F.
The first cooled displacement fluid recycle stream exits the preheater 804 in line 820 at a temperature of about 200° F. and enters an air cooler 806 (e.g., a cooler that cools the stream received from line 820 using air). The air cooler 806 cools the first cooled displacement fluid recycle stream received from line 820 such that the second cooled displacement fluid recycle stream exits the air cooler 806 in line 822 at a temperature of about 120° F.
The second cooled displacement fluid recycle stream flowing in line 822 then enters the dehydrator 808 to remove all or about all of the water from the second cooled displacement fluid recycle stream received from line 822. This resulting final displacement fluid recycle stream which emits from the dehydrator 808 in line 824, may have a composition of about 99 molar % or more carbon dioxide.
In one embodiment, for every 10 million standard cubic feet per day (MMSCFD) of residue gas (e.g., displacement fluid recycle stream gas), 836 million British thermal units (MMBTU) of energy is generated. For example, a residue gas may have a stream composition of about 92 molar % carbon dioxide, about 6.8 molar % methane, about 0.8 molar % ethane, and about 0.4 molar % propane. Thus, the hydrocarbons comprise about 8 molar % of the residue gas, methane comprises about 85 molar % of the hydrocarbons, ethane comprises about 10 molar % of the hydrocarbons, and propane comprises about 5 molar % of the hydrocarbons. Methane has a heating value of 910 British thermal units per a standard cubic foot (BTU/SCF), ethane has a heating value of 1630 BTU/SCF, and propane has a heating value of 2180 BTU/SCF. This results in methane providing 910 BTU/SCF×0.85=773 BTU/SCF, ethane providing 1630×0.10=163 BTU/SCF, and propane providing 2180 BTU/SCF×0.05=109 BTU/SCF. Accordingly, the total BTU/SCF of the hydrocarbons is 773 BTU/SCF+163 BTU/SCF+109 BTU/SCF=1,045 BTU/SCF. Therefore, for 10 MMSCFD of residue gas with a hydrocarbon content of 8 molar %, the amount of energy generated is 0.08×10,000 MCFD×1045 BTU/SCF=836 MMBTU. The 836 MMBTU of energy generated results in 33.5 MMBTU of net energy being available. This is due in part to the requirements for heating and cooling the fluids described in the processes above. In other embodiments, the carbon dioxide recycle stream fed to the catalytic reactor has an energy content of 50 BTU/SCF or more or 100 BTU/SCF or more. However, embodiments are not limited to any particular energy content values and may include other values as well.
This prophetic example is made with reference to the system 100 of FIG. 1, which processes a gas that is similar to an actual displacement fluid recycle gas sample taken from a gas well. The following process data is predicted using a commercial process simulation software.
The displacement fluid recycle stream used in this prophetic example has the following composition:
Concentration C2+ Flow C5+ Flow
Well Gas Component (mol %) (gpm) (gpm)
Nitrogen 2.259 0.000 0.000
Carbon Dioxide 91.778 0.000 0.000
Methane 2.865 0.000 0.000
Ethane 0.769 0.206 0.000
Propane 0.652 0.180 0.000
Iso-Butane 0.133 0.044 0.000
N-Butane 0.301 0.095 0.000
Iso-Pentane 0.114 0.042 0.042
N-Pentane 0.091 0.033 0.033
Hexanes and Heavier 0.363 0.158 0.158
H2S 0.675 0.000 0.000
(6753.6 ppm)
The gas of the above composition for processing in the system 100 has a specific gravity of 1.491 (measured at 600 psig and 131° F.), a gross wet heat content of 103 Btu/ft3 (measured at 14.650 psia and 60° F.), and a gross dry heat content of 105 Btu/ft3 (measured at 14.650 psia and 60° F.).
A gas of the above composition which is a miscible solution may flow as a displacement recycle stream from the recovery well 108 in line 111 at a pressure greater than or equal to atmospheric pressure through the one or more compressors 112, which compress the displacement fluid recycle stream to a pressure greater than about 300 psi and up to about 700 psi, for example, to a pressure of 500 psig. The compressed displacement fluid recycle stream then flows to the natural gas liquids (NGL) recovery unit 114 where C3+ components are removed and recovered as NGL product 116 via line 115. The C3+ components remaining in the displacement fluid recycle stream exiting the NGL recovery unit 114 in line 117 is:
C3+ Component in Line 117 Concentration (mol %)
Propane 1.87
Iso-Butane 0.00
N-Butane 0.06
Iso-Pentane 0.00
N-Pentane 0.00
Hexanes and Heavier 0.00
As can be seen, the concentration of propane in line 117 is lower than the concentration of propane in line 113; and iso-butane, n-butane, iso-pentane, n-pentane, and hexanes and heavier are completely removed from the gas in line 113 such that none of these components flow in line 117. The gas in line 117 may flow to the acid gas removal unit 118 where the H2S is removed completely for purposes of this prophetic example. The sweetened displacement fluid recycle stream of the following composition flows in line 120 to the catalytic reactor 102 at a pressure of 500 psig, a temperature of 120° F., and a molar flow rate of 20 MMSCFD, and a mass flow rate of 93,700 lb/hr:
Component in Line 120 Concentration (mol %)
Nitrogen 1.57
Carbon Dioxide 92.11
Methane 3.39
Ethane 1.01
H2S 0.00
In the catalytic reactor 102, the gas flowing from line 120 mixes with oxygen which flows from oxygen generator 122 via oxygen rich stream in line 128 and into the catalytic reactor 102 at a concentration of 100% oxygen, a pressure of 495 psig, a temperature of 120° F., a molar flow rate of 4 MMSCFD, and a mass flow rate of 14,000 lb/hr. The reaction(s) described herein are carried out in the catalytic reactor 102 such that hydrocarbon components are converted to carbon dioxide and the heat of the reactor 102 is used to generate steam in conjunction with the boiler 132 which provides steam to the power generator 136 for the generation of power as described hereinabove. The reacted displacement fluid recycle stream flows from the reactor 102 in line 130 at a pressure of 495 psig, a temperature of 2,454° F., a molar flow rate of 24.5 MMSCFD, a mass flow rate of 10,780 lb/hr, and having the following composition:
Water 14.32
As can be seen, almost all of the methane, and all of the ethane, propane, and n-butane of line 120 was converted in the catalytic reactor 102 such that the reacted displacement fluid recycle stream in line 130 contains only 0.02 mol % methane, and 0.00 mol % of ethane, propane, butane, and heavier hydrocarbons. The reaction(s) in the catalytic reactor 102 generate water, which flows in the reacted displacement fluid recycle stream in line 130 with the other components of said stream to the dehydrator 142 where water is removed. The dehydrated displacement fluid recycle stream flows from the dehydrator 142 at a pressure of 495 psig, a temperature of 150° F., a molar flow rate of 21.2 MMSCFD, a mass flow rate of 101,200 lb/hr, and having the following composition:
As can be seen, the concentration of water in the dehydrated displacement fluid recycle stream flowing from the dehydrator 142 in line 141 is 1.09 mol %, and the concentration of carbon dioxide is 97.41 mol %. The dehydrated displacement fluid recycle stream may flow via line 141 through one or more compressors such that the pressure of the gas is increased to a pressure in the range of 1,500 psig to 2,000 psi for reinjection into the injection well 106 via feed line 110.
As has been described above, embodiments of the present disclosure include a catalytic reactor for converting contaminants in a displacement fluid and generating energy. Certain embodiments may be beneficial in reducing the minimum miscible pressure of a carbon dioxide recycle stream, which can result in greater hydrocarbon recovery from a reservoir. Additionally, the heat generated by the catalytic reactor can be used to generate steam to operate a generator to produce power. Furthermore, the catalytic reactor can convert contaminants solely using catalytic reactions without the use of combustion. This can be useful in situations (e.g., high pressure and/or high carbon dioxide concentration) in which combustion is not possible.
At least one embodiment is disclosed and variations, combinations, and/or modifications of the embodiment(s) and/or features of the embodiment(s) made by a person having ordinary skill in the art are within the scope of the disclosure. Alternative embodiments that result from combining, integrating, and/or omitting features of the embodiment(s) are also within the scope of the disclosure. Where numerical ranges or limitations are expressly stated, such express ranges or limitations should be understood to include iterative ranges or limitations of like magnitude falling within the expressly stated ranges or limitations (e.g., from about 1 to about 10 includes, 2, 3, 4, etc.; greater than 0.10 includes 0.11, 0.12, 0.13, etc.). For example, whenever a numerical range with a lower limit, R1, and an upper limit, Ru, is disclosed, any number falling within the range is specifically disclosed. In particular, the following numbers within the range are specifically disclosed: R=R1+k*(Ru−R1), wherein k is a variable ranging from 1 percent to 100 percent with a 1 percent increment, e.g., k is 1 percent, 2 percent, 3 percent, 4 percent, 5 percent, . . . , 50 percent, 51 percent, 52 percent, . . . , 95 percent, 96 percent, 97 percent, 98 percent, 99 percent, or 100 percent. Moreover, any numerical range defined by two R numbers as defined in the above is also specifically disclosed. Use of the term "about" with reference to a numerical value includes values which are ±10% with respect to the referenced numerical value. Use of the term "optionally" with respect to any element of a claim means that the element is required, or alternatively, the element is not required, both alternatives being within the scope of the claim. Use of broader terms such as comprises, includes, and having should be understood to provide support for narrower terms such as consisting of, consisting essentially of, and comprised substantially of. Accordingly, the scope of protection is not limited by the description set out above but is defined by the claims that follow, that scope including all equivalents of the subject matter of the claims. Each and every claim is incorporated as further disclosure into the specification and the claims are embodiment(s) of the present disclosure. The discussion of a reference in the disclosure is not an admission that it is prior art, especially any reference that has a publication date after the priority date of this application. The disclosure of all patents, patent applications, and publications cited in the disclosure are hereby incorporated by reference, to the extent that they provide exemplary, procedural, or other details supplementary to the disclosure.
While several embodiments have been provided in the present disclosure, it should be understood that the disclosed systems and methods might be embodied in many other specific forms without departing from the spirit or scope of the present disclosure. The present examples are to be considered as illustrative and not restrictive, and the intention is not to be limited to the details given herein. For example, the various elements or components may be combined or integrated in another system or certain features may be omitted, or not implemented.
In addition, techniques, systems, subsystems, and methods described and illustrated in the various embodiments as discrete or separate may be combined or integrated with other systems, modules, techniques, or methods without departing from the scope of the present disclosure. Other items shown or discussed as coupled or directly coupled or communicating with each other may be indirectly coupled or communicating through some interface, device, or intermediate component whether electrically, mechanically, or otherwise. Other examples of changes, substitutions, and alterations are ascertainable by one skilled in the art and could be made without departing from the spirit and scope disclosed herein.
1. A method comprising:
receiving a carbon dioxide recycle stream that comprises hydrocarbons and 50 molar percent or more carbon dioxide;
feeding the carbon dioxide recycle stream to a catalytic reactor at a pressure greater than about 300 pounds per square inch (psi);
converting the hydrocarbons to carbon dioxide in the catalytic reactor by a catalytic reaction to form a purified carbon dioxide recycle stream, wherein the catalytic reactor comprises a shell and tube heat exchanger, wherein the shell and tube heat exchanger comprises an outer shell with a plurality of tubes within, wherein a volume of the shell and tube heat exchanger between the outer shell and the plurality of tubes is configured to boil a fluid, wherein a volume within the plurality of tubes comprises a catalytic material, wherein the catalytic material comprises a metal supported by an inorganic support, wherein the catalytic reaction occurs by passing the hydrocarbons through the catalytic material within the plurality of tubes, and wherein the catalytic reaction converts the hydrocarbons and oxygen to the carbon dioxide, water, and heat; and
generating electrical energy by using the heat produced by the catalytic reactor in the conversion.
2. The method according to claim 1, further comprising removing C3+ hydrocarbons from the carbon dioxide recycle stream before the carbon dioxide recycle stream is fed to the catalytic reactor.
3. The method according to claim 1, wherein the carbon dioxide recycle stream has an energy content greater than about 50 British thermal units per standard cubic foot (BTU/SCF).
4. The method according to claim 1, further comprising feeding the purified carbon dioxide recycle stream to a hydrocarbon injection well.
5. The method according to claim 1, wherein generating the electrical energy comprises producing steam from the heat generated by the catalytic reactor and operating an electrical generator using the steam.
6. The method according to claim 1, wherein the metal comprises one or more of nickel, iron, and a noble metal, and wherein the inorganic support comprises one or more of silica and alumina.
7. The method according to claim 6, wherein the noble metal comprises one of palladium, platinum, silver, gold, iridium, osmium, rhodium, and ruthenium.
receiving a recycle stream that comprises carbon dioxide, C1-C2 hydrocarbons, and C3+ hydrocarbons;
separating the C3+ hydrocarbons from the carbon dioxide and the C1-C2 hydrocarbons;
feeding the carbon dioxide and the C1-C2 hydrocarbons to a catalytic reactor at a pressure greater than about 300 pounds per square inch (psi); and
converting the C1-C2 hydrocarbons and oxygen to carbon dioxide, water, and heat in a catalytic reaction,
wherein the catalytic reactor comprises a shell and tube heat exchanger,
wherein the shell and tube heat exchanger comprises an outer shell with a plurality of tubes within,
wherein a volume of the shell and tube heat exchanger between the outer shell and the plurality of tubes is configured to boil a fluid,
wherein a volume within the plurality of tubes comprises a catalytic material,
wherein the catalytic material comprises a metal supported by an inorganic support,
wherein the catalytic reaction occurs by passing the hydrocarbons through the catalytic material within the plurality of tubes, and
wherein the catalytic reaction converts the C1-C2 hydrocarbons and the oxygen to the carbon dioxide, the water, and the heat using the catalytic material in the catalytic reactor.
9. The method according to claim 8, wherein the recycle stream is received from a hydrocarbon recovery well, and wherein the method further comprises feeding a purified carbon dioxide recycle stream to a hydrocarbon injection well.
10. The method according to claim 8, further comprising:
separating air into oxygen and nitrogen; and
feeding the oxygen to the catalytic reactor.
11. The method according to claim 8, further comprising generating energy using the heat.
12. The method according to claim 8, wherein the metal comprises one or more of nickel, iron, and a noble metal, and wherein the inorganic support comprises one or more of silica and alumina.
13. A set of process equipment comprising:
a natural gas liquids (NGL) recovery unit configured to receive a recycle stream comprising carbon dioxide, C1-C2 hydrocarbons and C3+ hydrocarbons, and to separate the recycle stream into an NGL stream and a carbon dioxide recycle stream, wherein the NGL stream comprises C3+ hydrocarbons, and wherein the carbon dioxide recycle stream comprises carbon dioxide and C1-C2 hydrocarbons;
a catalytic reactor configured to receive the carbon dioxide recycle stream and convert the C1-C2 hydrocarbons in the carbon dioxide recycle stream to carbon dioxide by a catalytic reaction to produce a purified carbon dioxide recycle stream, wherein the catalytic reaction converts the C1-C2 hydrocarbons to the carbon dioxide using a catalyst in the catalytic reactor, wherein the catalytic reactor comprises a shell and tube heat exchanger, wherein the shell and tube heat exchanger comprises an outer shell with a plurality of tubes within, wherein a volume of the shell and tube heat exchanger between the outer shell and the plurality of tubes is configured to boil a fluid, wherein a volume within the plurality of tubes comprises a catalytic material, wherein the catalytic material comprises a metal supported by an inorganic support, wherein the catalytic reaction occurs by passing the hydrocarbons through the catalytic material within the plurality of tubes, and wherein the catalytic reaction converts the C1-C2 hydrocarbons and oxygen to the carbon dioxide, water, and heat; and
a dehydrator configured to remove the water from the purified carbon dioxide recycle stream and feed the dehydrated purified carbon dioxide recycle stream to a hydrocarbon injection well for use in an enhanced oil recovery operation.
14. The set of process equipment according to claim 13,
wherein the shell and tube heat exchanger is configured to generate steam.
15. The set of process equipment according to claim 14, further comprising a steam turbine power generator that is configured to use the steam from the shell and tube heat exchanger to generate electricity.
16. The set of process equipment according to claim 13, further comprising an oxygen generator that is configured to feed the catalytic reactor with oxygen that is generated by separating air into oxygen and nitrogen.
17. The set of process equipment according to claim 13, further comprising an acid gas removal unit positioned between the NGL recovery unit and the catalytic reactor, wherein the acid gas removal unit is configured to remove acid gases from the carbon dioxide recycle stream.
18. The set of process equipment according to claim 13, wherein the metal comprises one or more of nickel, iron, and a noble metal, and wherein the inorganic support comprises one or more of silica and alumina.
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HOME | OUR SPEAKERS | Richard Pascale
Richard Pascale keynote speaker
Management Strategist
pascale@gspeakers.com
Creating and Sustaining Agility
Managing from The Future
Re-Inventing the Organisation
Risking the Present for a Powerful Future
Richard Pascale is an Associate Fellow of Oxford University.
He was a member of the faculty of Stanford's Graduate School of Business for twenty years. He taught the most popular course in their MBA program-a course on organizational survival.
He is a leading business consultant worldwide, a best-selling author and a respected scholar.
As an advisor to CEOs and senior executives of many Fortune 500 companies, his work addresses the intersection of strategy and organization. His specific expertise encompasses the design, facilitation and mobilization of large scale organizational change in pursuit of strategic intentions.
He received his MBA and doctorate from Harvard Business School and was a Baker Scholar. Pascale's current and former clients include AT&T, BAE Systems, British Gas, British Petroleum, Cable and Wireless, Ciba Geigy, Coca Cola, Cummins, Diageo, Genentech, General Electric, Goldman Sachs, Guinness, Intel, JP Morgan/Chase, Levi Strauss, Motorola, The New York Times, and Royal Dutch/Shell.
In conjunction with articles and books, he has conducted extensive research at BP, Ford, General Electric, General Motors, Honda, Matsushita, Monsanto, Sears and Shell. Pascale served as advisor in Iraq to U.S. Ambassador Zalmay Khalilzad during the summer of 2005. This work entailed the transition of the new ambassador into his post and the management of the largest U.S. mission in the world.
He was a White House Fellow, Special Assistant to the Secretary of Labor and Senior Staff of a White House Task Force.


Sorry, registration for the current C3 for Success program is closed; please contact Nan directly if you'd like to join the waiting list for the next C3 for Success Coaching Circle.
Join an eight-week virtual Confidential Coaching Circle limited to only six mid-career women attorneys, and master the skills and strategies you need to succeed in your legal career. Starting April 30, 2013, and led by former law firm partner and certified executive coach Nan Joesten, the group will engage in six structured, one-hour weekly conference calls. Each call features Nan's brief presentation on a variety of topics (detailed at C3 for Success ), followed by group discussion of personalized action steps that Circle members are taking to reach their goals. You will also receive two private one-hour coaching sessions with Nan in place of the group coaching call during weeks Four and Eight. C3 culminates with each Circle member creating their personal strategic plan for the next six months, getting feedback from Circle members on your plan, and setting up your own Personal Board of Directors for ongoing encouragement and support as you pursue your goals. For questions, or to register to join C3 for Success, contact Nan at (510) 217-8900.
Business owners and executives must now solve more problems sooner, with fewer resources, than ever before. Rapid Evolution's executive coaching services can help you not just survive, but thrive, in today's challenging business environment. No busy executive can be expected to master, on their own, every situation they're confronted with. That's why having a confidential "thought partner" to help you identify and leverage your strengths to greater success will help you accelerate your professional development and allow you to deliver better results than you could working alone.
Thankfully Dr. Seuss wasn't right that you're entirely on your own. An executive coach, whether hired by your firm to work with you, or someone you retain directly, engages with you as your "thought partner" in a structured process that is goal directed by you towards your developmental objectives.
The number one reason organizations engage Nan Joesten as a coach is to develop their high potential individuals, or to smooth transitions. Individuals also hire Nan directly to enhance their own development, or achieve particular objectives. As organizations flatten, product cycles hit hyperspeed, and change is constant, Nan's executive coaching can help you become a better, more relaxed, and more nimble business leader.
A 2001 study examined 100 mid- to senior-level managers at large organizations who participated in coaching, and they estimated their coaching to be worth 5.7 times the initial investment. The benefits were both organizational (better productivity, quality, organizational strength, customer service, and retention), as well as personal (improved relationships with direct reports and peers, better teamwork, and increased job satisfaction). An earlier study of 370 coaching participants found significant improvements in specific learning objectives that were targeted in the coaching, as rated by participant, manager and coach. Coaching produced an average change roughly equivalent to moving from the 50th to the 93rd percentile of performance. How much will executive coaching benefit you?
An organization's emerging and high potential leaders are ideal candidates for Rapid Evolution's executive coaching focused on increasing emotional intelligence. People who have advanced due to their technical expertise often struggle in making the transition from co-worker to manager, and the technical genius often makes for a poor boss. Because emotional intelligence can be developed, coaching focused on emotional intelligence has a high return on investment.
Leaders wishing to develop their emotional intelligence typically begin a coaching engagement by completing a confidential formal assessment focused on leadership and various aspects of emotional intelligence, such as the Spectrum CPI 260™ Coaching Report for Leaders. The Report provides an assessment on eighteen factors broken into five core performance areas of star performers: Self Management, Organizational Capabilities, Team Building and Teamwork, Problem Solving, and Sustaining the Vision. Working with Nan, the coachee then determines the four to five factors in which they wish to be a peak performer in the emerging phase of their career, and begins developing concrete action plans for accelerating their growth in these areas.
Many executives hired for top leadership roles describe their onboarding process as "sink or swim," which helps explain why 40% of them fail in the first 18 months. It's a costly breakdown for the organization, as executive turnover in year one is valued at roughly three times the executive's salary. And beyond the damage to the individual and the loss of realized value from talent acquisition investments, the organization must also contend with the slow erosion of confidence and the loss of talent magnet power.
Where team members lack trust in one another or their leaders, results and morale suffer, and attrition is more likely. Most teams want to be higher performing and collaborative, but that does not guarantee the desired outcome. Where team leaders or their key members do not have experience in strong team settings, they can benefit from Rapid Evolution's targeted executive coaching to improve their team's effectiveness.
With the coachee's agreement, Nan's coaching engagements typically begin some type of a confidential formal assessment, such as the Leadership Practices Inventory® multi-rater 360 assessment, the Myers Briggs Type Instrument® (Step II), or the Spectrum CPI 260™ Coaching Report for Leaders. An assessment helps the executive better understand their preferences, attitudes, and behaviors in key dimensions of management and leadership, and is an efficient way for them to understand and capitalize on their personal strengths, target areas for further development, set goals, and plan action steps. The Spectrum CPI 260™ Coaching Report for Leaders is a particularly useful assessment for executives who want to enhance their emotional intelligence through the use of coaching.
After the initial assessment of an individual's inventory of social and emotional preferences, Nan inspires emerging leaders to identify their strengths and strategize how best to leverage those abilities to deliver better results. Clients determine their top opportunities for growth, and develop an action plan to accelerate their development in those areas.


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Who is more trusting? People with private or public profile?
"There are two sides to every coin".
I have many friends who use Instagram. I often hear different views, some love it for the content, some are annoyed to see people not presenting their real self. There are always two sides, being online can make you happy or unhappy; connected or isolated; confident or losing more self-esteem…the same technology but with different effects.
Better decisions
Our responsive behaviours online become intriguing for researchers like me to better understand the impact of technology. Over the years, some friends have closed their social media accounts due to privacy concerns and others are using social media for everything. Personally, I love social media but have seen both the good and bad sides of it. I even tried doing a social media detox and have also noticed myself switching between private to public from time to time. When it comes to how we use social media, there is no simple right or wrong decision. We make the best decision for ourselves with what we know. To me, the more important part is how to make better decisions so we can actively avoid the negatives. This where Cyberpsychology - a study of human behaviours and technology - can help.
It's a paradox
Trust on is particularly important because there are 3 billion people who spend an average of 2.5 hours a day on social media. That's a lot of information being collected, shared and viewed by family, friends and complete strangers. There are many reasons that we use and post on social media, one of them is self-disclosure. It's human nature to want to share our experiences. Creating a social media profile fulfils the needs of social connectedness and belonging, but the process of disclosure can also reduce privacy. We need trust to disclose, but the more we disclose online, the less privacy we have. With less privacy, do we expose ourselves to more risks? With more risks, do we trust less? There are a lot of questions about this shared paradoxical relationship.
"Trust is a confident relationship with the unknown." - Rachel Botsman
Why is trust important? Let me ask you a question? Have you ever had a successful and happy relationship for distrusting someone? Rachel Botsman explained in her TedTalk that not trusting is riskier because it can cost us valuable relationships and opportunities, while trusting can open up personal and commercial opportunities especially for collective consumption such as Airbnb. A business which was made possible because of technology and trust.
Almost everything we do on social media is linked to trust. Do we trust that the platform will protect our data? Do we trust what we read? Do we trust others to see our posts? Who do we trust to see our photos? And the list goes on. While social media continues to transform us, our changing behaviours on social media become fascinating for researchers. My interest for my Masters dissertation was in the responsive behaviour of selecting profile privacy status.
On Instagram for instance, there are two distinct statuses: A private or public profile. Setting your profile status is a common way to protect your privacy. Over half of people on social media have changed their privacy settings according to European Commission guidelines. If you change your profile to private, you will limit the self-disclosed information to approved friends only. I was interested in how this behaviour indicates our trust and maybe even changes our trust? There was no information I could find so I designed a research study to find the answer to the question:
If you have a private Instagram account, do you have a higher or lower level of trust, compared to those who have a public account? (What is your guess?)
People with private profiles generally have a higher level of trust than people with public profiles.
Is this the same as what you thought?
Existing research can provide some explanation to this. Based on the well-known Communication Privacy Theory (CPT), higher trust is indicative of stronger privacy boundaries, that is what private profiles provide. The private profile offers individual protection to the owner but also collectively to people who are linked to the owner.
My research study involved 59 participants and their profile privacy status and general levels of trust. The correlations between their status and level of trust were strong but what about impact of privacy status on others? Does profile change our trust?
The second part of my study was about whether being exposed to a certain type of privacy status will alternate our level of trust. The results only showed that users with private accounts actually increased their level of trust regardless what types of profile they were exposed too. I was hoping to find a stronger link to the Cultivation Theory which suggests that persistent exposure cultivates one's world view. There are many possible explanations, but only future research can tell us how profiles can change our view on trust.
We share our information on social media to establish trust. However using social media can also take away our trust. Understanding, protecting and nurturing our trust is paramount, especially in the digital era.
Placing our trust in people to bring happiness, enjoyment and prosperity is our main goal. I remember watching Rachel Botsman's Tedtalk back in 2008 and being overwhelmed by her idea that "The currency of the new economy is trust". Just look at the example of Airbnb again, it is a collaborative consumption that empowers people to make meaningful connections. No one would have thought that letting strangers stay in your house would become one of the biggest businesses in the world, before Covid-19 anyway. This pandemic has also been a fascinating topic for researchers from how stories were told, how fear and misinformation can affect our trust in others.
We, as a user of any sort of technology, whether it is social media or a virtual meeting tool, have the power to make decisions on how it is affecting us and how it is affecting others.
Remember, there are two sides to every coin. For example, we can either decide to build more trust, or alternatively, allow trust to be taken away! The good news is that people are very good at evolving and learning to make better decisions. That is what motivates me to continue exploring and helping others to be happier with technology. After all, technology and social media are not going away anytime soon.
Jing Reilly, an evolving human on a mission to make positive impact, one person at the time.


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A total of 92 per cent Indians polled by independent market research company Ipsos view global warming and climate change as major threats.
The government on Monday informed Parliament that the energy sector in the country was the biggest emitter of greenhouse gas (GHG) emissions.
Indian Railways will be funding a railway research chair on sustainable mobility at TERI University. The railway ministry entered into a memorandum of understanding (MoU) with TERI University recently.
The richest 10 % of people produce half of the Earth's carbon emissions, while the poorest half-most threatened by droughts and super stroms linked to climate change--contribute a mere 10%, British charity Oxfam said in a study released on Wednesday.
Carbon capture technology firm Climeworks AG, says it will construct and operate an industrial-scale CO2 capture plant that will be operational by mid-2016 and annually capture 900 tons of CO2.
Microsoft has, as of July 1, 2015, achieved carbon neutrality across its manufacturing operations, according to the company's 2015 Citizenship Report.
Apple is taking further steps to reduce the environmental impact of its huge Chinese supply chain, with plans announced today to build 200 megawatts of solar farm capacity across the country and work with partners to boost manufacturing efficiency.