CO2 Sequestration Poll for Darke County on DarkeJournal.com

Thank you, Darke Journal for conducting this poll - and many thanks to our residents who voted in the poll against the proposed CO2 sequestration project in Greenville, Ohio.

www.darkejournal.com

As you will recall, The Daily Advocate, did a poll prior to our Call to Action Meeting the end of June.... results below

Click here to be taken to the poll


PLEASE NOTE: This poll was conducted prior to the past month’s concerted effort to educate and inform the public regarding the proposed sequestration.



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Published July 1, 2009



Recently, The Daily Advocate sent out a Reader’s Poll to online newsletter subscribers about the proposed carbon sequestration project in Greenville. The poll consisted of 10 questions based on concerns the newspaper was receiving from local residents.



The poll was sent out to 2,268 subscribers and received 161 responses.

Of the 161 responses, 73 percent felt that there should be a public vote on the proposed project.



“How do we stop this project? The people of the county should decide what happens,” wrote on respondent.



“A public vote is the best way to go. Why? Because the co2 sequestration affects all our properties, all our jobs, and all of our community not just a select few government leaders who ‘should’ be representing the county,” wrote another.



“This project should be voted on by the public.We the public and our children will be the ones who will have to live with the after effects for years and years to come,” said another.



Many others (40 percent) felt that the project needed local government approval to move forward.



Concerns were other big issues. Fifty-nine percent said that local farmers should be concerned about the impact of the project.



And, 36 percent said that the project would impact their property’s value. Fifty percent said that the project was dangerous.



“I do not feel this project is in the best interest of OUR community! It’s an experiment with too many risk factors, especially when it’s messing with our fresh water supply,” states one individual.



“This is a threat to our lifestyle and our community and me and my family are strongly opposed to anything to do with this project. Battelle can take this project back to the city with them,” another person strongly stated.



The majority did not feel that the project was a good idea for the community (59 percent) or that it would make our community more ‘green’ (50 percent).



Respondents strongly agreed that they needed more information about the project (55 percent) and that Battelle, the company proposing the project, did not seem very committed to the well being of the

community (44 percent). Thirty-eight percent of respondents said that the project should provide a reward to the community for taking the risk.



Read more comments from the respondents on the Web site at

http://www.advocate360.org

CCS Guidelines from WRI

These excerpts come from this link

Principles for Meaningful Community Engagement
(1) Identify stakeholders early. X
(2) Define the intended outcomes of community engagement. X
(3) Determine whether to inform, consult, or negotiate. X
(4) Engage communities throughout the project cycle. X X X X X
(5) Allow communities to raise grievances. X X X X
(6) Promote internal and external monitoring. X X X X

SOUR C E : HE R B E R T SON 2 0 0 8

(note - allowing communities to raise grievances - interesting that there is no conflict resolution mentioned or considered)


Water Use

"Power plants, with or without CO2 capture, use large amounts of water."

"Note that water use for PC power plants more than doubles with the addition
of capture equipment."

"The impacts of increased water use associated with CO2 capture are related to the increased need for system cooling. As an alternative to wet cooling, facilities could use dry cooling technologies. There is a trade off between energy use and water use when dry cooling is employed. As a facility reduces water use, it increases energy use, which creates an additional energy penalty."

(Note- since the ethanol plant has been operating, we have had water issues and many wells go dry in the area close to it and now this calls for even MORE water, our most precious resource)


Seismic Activity (Page 74)

" The presence of seismically active faults does NOT exclude a site from either holding CO2 or being considered for storage, although a strong demonstration must be made that there would
be no risk of leakage resulting from seismic activity. There are many places in the world where large volumes of buoyant fluids (e.g., oil, gas, and CO2) are trapped indefinitely in the presence
of seismic activity, including California, Wyoming, Alaska, Turkey, Western Australia, Papua New Guinea, Indonesia, and Iran. After the injection of almost 9,000 metric tons of CO2 in the
Nagaoka CCS demonstration, operations were disrupted by the Mid-Niigata Chuetsu 6.0-magnitude earthquake. Following careful evaluation, it was determined that the wells, the
reservoir, and the facility were intact and undamaged, and injection resumed (RIITE 2008)."


" Many aspects of a fault affect its ability to trap CO2 at a site. These include the geometry of the fault, its complexity, the orientation of the fault relative to regional stresses, the amount
and distribution of fault goug e, and the occurrence of either elevated or reduced pressure nearby (Yielding 1997). In some cases, it is relatively straightforward to obtain key pieces of
information that can be used to understand the potential risks presented by a fault or network of faults. Recently, Chiaramonte et al. (2007) gathered information to estimate the potential for
faults within one oil field to transmit CO2. In their calculation, one fault had a very low chance of becoming transmissive, and would require injections well above reasonable operational
pressures to act as a leakage conduit. In contrast, another fault network in a different part of the field would act as a conduit for CO2 in the presence of even a small injection. If this were an
operational site, the southern part of the field would be a good zone of storage, while the northern part would not because of the possibility for transmissive faults at operational pressures."

"This example highlights the need for careful site characterization in selection and the importance of high-quality data. The presence of large, active faults should not necessarily preclude prospective sites from selection as storage sites. Rather, the complex nature of faults in and associated with potential injection sites must be characterized, considered, and managed as part of a risk assessment and MMV plan. Hazard identification should focus on faults that could be transmissive within the injection reservoir or confining zone and expected project footprint, as faults only represent a substantial hazard if they can transmit large volumes of CO2."

(Note - the people who plan and conduct these risky experiments do not live in these communities nor do they have plans to live in them - In our community residents have been told that once CO2 injection enters the picture their homeowner's insurance will not cover man-made earthquakes.

CO2 Pipelines - from WRI

Although CO2 pipelines are classified as hazardous, CO2 is not defined as a
hazardous substance. It is a Class L, highly volatile, nonflammable/nontoxic
material (CFRg, CFRe, Appendix B, Table 4).

CO2 pipelines are treated as hazardous and are reviewed as high-risk hazardous pipelines when they have a diameter greater than 457mm(18 in) or when they pass through High-Consequence Areas.

States certified to regulate intrastate pipelines are: Alabama, Arizona, California, Louisiana, Maryland, Minnesota, Mississippi, New York, Oklahoma, New Mexico, Texas, Virginia,Washington, and West Virginia.

49 CFR § 195.2 defines low-stress pipeline as a hazardous liquid pipeline that is
operated in its entirety at a stress level of 20 percent or less of the specified minimum-yield strength of the pipeline (CFRf).

49 CFR § 195.2 defines rural area as an area outside the limits of any incorporated or unincorporated city, town, village, or any other designated residential or commercial area, such as a subdivision, a business or shopping center, or community development. The rural areas are considered to be the nonenvironmentally sensitive areas (CFRf).

An easement is a limited perpetual interest in land that allows the pipeline owner
to construct, operate, and maintain a pipeline across the land. An easement does
not grant an unlimited entitlement to use the right of way. The rights of the
easement owner are set out in the easement agreement.

Eminent domain is the power of government to take private land for public use.
Under current law there is no federal eminent domain power granted for the
construction of CO2 pipelines. A number of states, however, do allow the use of
eminent domain for CO2 pipeline construction under certain conditions.

The information above comes from the link below -

From WRI - World Resources Institute CCS Guidelines - this information is found on page 52

A System Model for Geologic Sequestration of Carbon Dioxide

Read the full article here

In this paper we describe CO2-PENS, a comprehensive system level computational model for performance assessment of
geologic sequestration ofCO2. CO2-PENS is designed to perform probabilistic simulations of CO2 capture, transport, and injection in different geologic reservoirs. Additionally, the longterm fate of CO2 injected in geologic formations, including
possible migration out of the target reservoir, is simulated. The
simulations sample from probability distributions for each
uncertain parameter, leading to estimates of global uncertainty
that accumulate through coupling of processes as the simulation time advances. Each underlying process in the systemlevel model is built as a module that can be modified as the simulation tool evolves toward more complex problems. This approach is essential in coupling processes that are governed by different sets of equations operating at different timescales. We first explain the basic formulation of the system level model, briefly discuss the suite of process-level modules that are linked to the system level, and finally give an in depth example that describes the system level coupling between an injection module and an economic module. The example shows how physics-based calculations of the number of wells required to inject a given amount of CO2 and estimates of plume size can impact long-term sequestration costs.

Read the full article here

Research for Deployment: Incorporating Risk, Regulation,and Liability for Carbon Capture and Sequestration

Carbon capture and sequestration (CCS) has the potential to enable deep reductions in global carbon dioxide (CO₂) emissions, however this promise can only be fulfilled with large-scale deployment. For this to happen, CCS must be successfully embedded into a larger legal and regulatory context, and any potential risks must be effectively managed. We developed a list of outstanding research and technical questions driven by the demands of the regulatory and legal systems for the geologic sequestration (GS) component of CCS. We then looked at case studies that bound uncertainty within two of the research themes that emerge. These case studies, on surface leakage from abandoned wells and groundwater quality impacts from metals mobilization, illustrate how research can inform decision makers on issues of policy, regulatory need, and legal considerations. A central challenge is to ensure that the research program supports development of general regulatory and legal frameworks, and also the development of geological, geophysical, geochemical, and modeling methods necessary for effective GS site monitoring and verification (M&V) protocols, as well as mitigation and remediation plans. If large-scale deployment of GS is to occur in a manner that adequately protects human and ecological health and does not discourage private investment, strengthening the scientific underpinnings of regulatory and legal decision-making is crucial.

Potential Groundwater Quality Impacts from Metals Mobilization.

Groundwater merits special attention because it is a precious resource, and it is subject to current regulation. While there are several ways in which large-scale injection or leakage might affect water supplies, most attention has focused on CO₂−brine−rock interactions. While processes in this system could affect both organic and inorganic geochemistry of aquifers, only the mobilization of inorganic compounds, chiefly metals, through dissolution and transport will be considered here.

South Liberty (Frio) Pilot, TX.

In 2004, a DOE pilot field experiment in South Liberty, TX injected 1800 t of CO₂ into the Frio saline formation (29). This injection was designed to validate simulations of CO₂ transport and fate in one of the largest saline formations in the United States. A monitoring well located 100 ft. from the injection well collected direct fluid samples using a U-tube apparatus (30). This tool and others detected arrival of a CO₂ plume in the monitoring well 7 days after injection.

Of note, a substantial amount of dissolved metal was recovered in the U-tube (31). Initially, workers thought that the well casing was reacting to carbonic acid in the reservoir. However, laboratory studies and geochemical analyses confirmed that a substantial fraction of the metals were the product of mineral dissolution, specifically the oxide and hydroxide coatings of mineral grains that represent <2%>31). The rapidity of mobilization and the high concentrations suggested strongly that carbonic acid formed from dissolved CO₂ in formation brines might quickly and dramatically alter groundwater chemistry.

The Frio was the first saline formation analyzed in this way. Ultimately, this result is not unexpected, yet it is not clear whether this effect of metal mobilization is common or significant at depth. It is also not clear what fraction of metals would be transported with CO₂ should it leak to other formations. However, it raised the concern that should CO₂ leak into a shallow freshwater aquifer, there could be consequences that could negatively affect groundwater quality, potentially impacting public health and acceptance of CCS deployment.

Carbonate and Siliclastic Systems.

To a first order, both injection targets and shallow aquifers can be divided into siliciclastic or carbonate systems. This division reflects the primary composition of the reservoir rocks. Carbonate systems chiefly comprise calcite, aragonite, dolomite, and other carbonate minerals that form limestones and dolostones, whereas siliciclastic systems chiefly comprise frag ments of quartz, feldspar, and other siliceous minerals that form sandstones, siltstones, and shales.

This compositional difference greatly affects the response of carbon acid. Silicate minerals react slowly with CO₂, which means that there is little change in porosity and permeability over the duration of injection; however, the brines with dissolved CO₂ will remain acidic. In contrast, carbonate rocks react quickly with CO₂ and could change permeability and porosity quickly; however, the rapid kinetics will result in rapid increase of brine pH and buffering of the brine−CO₂ system, reducing reactivity over time. Because of these competing effects, it is not clear which fundamental rock composition is more prone to leakage or to mobilizations of metals, and little work has focused on direct comparison of these two primary aquifer compositions.

Key U.S. Freshwater Aquifer Settings.

Given the distribution of CO₂ point sources and potential GS reservoirs, it is likely that CO₂ storage will be concentrated in a small number of basins. To understand and appraise the potential for metal mobilization in shallow aquifers, it would be helpful to understand the composition and acid-reaction response near the surface of these basins. Table 2 provides a subset of key shallow aquifers in these basins and some issues around their geology.

From National Commission on Energy Policy- CCS

Read the full article here - http://www.energycommission.org/ht/action/GetDocumentAction/i/3054
Below are a few excerpts from the National Commission on Energy Policy -

Although the theoretical carbon-storage capacity of underground geological repositories in the United States is plentiful, large-scale deployment of CCS would nevertheless require significant investments in infrastructure, possibly including thousands of miles of dedicated carbon dioxide pipelines.

In addition, under optimistic deployment scenarios, many thousands of wells could be required to inject carbon dioxide into underground repositories.

Whether this type of infrastructure would be likely to encounter significant obstacles related to siting and public acceptance is an open question. The limited research available on this topic—most of which has focused on general perceptions of CCS, rather than on likely public reaction if new wells and reservoirs are proposed for a specific community— suggest that CCS is not well known or understood by the public. When introduced to CCS along with a range of other options, most respondents prefer what they consider to be alternatives such as energy efficiency or renewable energy for reducing emissions.45

In sum,efforts to educate the public about CCS and to provide for public input on related siting and other decisions are likely to be critical to advancing this technology.

No provisions are in place, however, to regulate the long-term storage of carbon dioxide which—because it would require measures to prevent venting back to the atmosphere—could involve
new provisions for risk assessment, for monitoring the performance of wells, for assuring the permanence of the carbon stored, and for managing long-term liability if a reservoir leaks.

Large-scale CCS projects would likely also require the assessment of additional risks, including the risk of large releases of carbon dioxide to nearby population centers, risks to groundwater quality, and risks from reactivity with underground minerals and solutions.

Carnegie Mellon team makes sequestration recommendations

Carnegie Mellon team makes sequestration recommendations

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These might look like good suggestions, UNLESS you happen to live where they plan to inject it.
I believe we'd be more comfortable with this if the same scale CCS project was first implemented under the state capital

As with anything that changes and/or impacts the environment, the people living there should have a vote!

CO2 Sequestration - A Ticking Time Bomb?

Many thanks to the unknown photographer who took, tweaked and sent this photo -

Darke County Ohio is speaking out AGAINST CO2 - please see the Daily Advocate and its CO2 blog for many related articles.


Please see our web site to order "No CO2 pins, T-shirts, Yard Signs or Car Window Clings"
Look for us downtown during the Annie Oakley Parade

Well Construction and Mechanical Integrity Testing

Synthesis, Evaluation and Assessment of
USEPA Technical Workshop on Geosequestration:
Well Construction and Mechanical Integrity Testing

Jerry Thornhill, P.G.
Consultant to Shaw Environmental, Inc.
Randall Ross, Ph.D.
Steven Acree, P.G.

National Risk Management Research Laboratory
Prepared under contract to Shaw Environmental, Inc.
Contract Number 68-C-03-097

www.regulations.gov/search/redirect.jsp?objectId...disposition..

EXECUTIVE SUMMARY
Injection and monitoring wells employed for the geologic sequestration of CO2 may be
required to operate for timescales that go beyond the operating lifespan traditionally
considered by the oil and gas industry. Lessons learned from pilot studies and
conventional injection practices may provide some general guidance for the geologic
sequestration of CO2. However, the special problems related to the unique properties of
supercritical CO2 and proposed massive injection volumes may ultimately require the
development of new materials and tools to reduce the risk of failure and, possibly, new
regulations to manage the risks.
Several key issues regarding well construction and MIT with respect to geological
sequestration of CO2 were identified during this workshop.
Well Completion
Although well integrity is the cornerstone for successful injection well projects, an
integral part of a successful project is the initial well completion program (i.e., drilling
the hole, setting and cementing casing, setting tubing, etc.). This is vital to the successful
operation of any injection well project. The choice of casing and tubing material, cement
type, amount, and proper emplacement is the starting point for the success of the injection
well.

During the workshop, it was stated that,
“Wellbore integrity problems do exist in oil and gas operations and are often due
to cementing practices.”

This statement was apparently based on information from meetings of the International
Energy Agency (IEA) Greenhouse Gas R&D Programme. Key findings from the IEA
March 2006 meeting (IEA, 2006) included, “Well integrity may be a current issue within the oil and gas industry. A detailed study on production wells in the Gulf of Mexico indicated that up to 60% of wells had casing pressure problems, which could indicate that the integrity of the wells
had been compromised.

Experience from the Permian basin in the USA indicated that when fields were changed over to CO2 floods that significant remedial work was needed to pull and re-cement wells that had not seen exposure to CO2. It was considered that many of the problems in both the Gulf of Mexico and the Permian basin resulted from poor well completions at the outset.”

An injection well must be completed in such a manner that underground sources of
drinking water (USDWs) are protected initially, during long-term injection operations,
and following the period of injection. This includes well completion to provide protection
of ground water from naturally occurring salt-water zones; well completion to keep the
injectate in the proposed injection zone and capability to detect any equipment failure
resulting from such things as corrosion, inadequate or unsuccessful cement emplacement,
channeling around an initially successful cement sheath, or mechanical failure.

A specific concern of the participants in the Well Construction breakout session was the
casing metallurgy/coatings in view of the corrosive nature of the CO2. This is especially
critical for the long string casing, tubing and packers that would be in contact with the
injectate.

Participants in the Well Construction breakout section generally felt that the
Underground Injection Control (UIC) Class I requirements “may” be sufficient for CO2
geologic sequestration. It is recommended that Class I requirements be the minimum
standard considered for CO2 injection.

It has been determined that Portland-based cements react with CO2, leading to cement
degradation. Research has indicated that interaction between cement and CO2 follows a
three-step process - carbonic acid diffusion, dissolution/carbonation, and leaching. This
generally leads to loss of density and strength and an increase in porosity.

From the Los Alamos National Laboratory
Key issues identified by the Network include:
• Wellbore integrity problems exist in oil and gas operations and are often related to
cementing practices.
• Research is needed on reactivity of CO2 and cement to reconcile effects of key
variables.
• Methods for determining performance of new CO2-resistant cements are needed.
• Corrosion of tubulars and casing can be more rapid than cement degradation.
• More sensitive field monitoring tools for diagnosing well integrity are needed.
• Numerical models of wellbore geochemistry and geomechanics are needed.
• Numerical models incorporating realistic well permeability distributions are
needed to evaluate leakage potential.
• Evaluation of existing fields with long term CO2 exposure are needed to develop
more effective methods for logging/monitoring for evaluating mechanical
integrity.
• Mining of existing data from private companies and regulatory authorities should
be a priority for development of a statistical basis for evaluating wellbore
performance.


CO2-Cement Interaction: From the Lab to the Well
Matteo Loizzo, Schlumberger Carbon Services Engineering

The presentation summarized research on CO2/cement reactions and the development of CO2-resistant cement. The interaction between Portland cement and CO2 is a 3-step process:
• Carbonic acid diffusion,
• Cement (portlandite) dissolution and carbonate precipitation, and
• Leaching (calcium carbonate dissolution).
Cement sheath defects would cause acceleration of the degradation process. Potential
defects include:
• Inadequate placement of cement resulting in channels or mud films,
• Channels caused by gas migration during cement hydration,
• Cracks caused by cement failure in compression/traction, and
• Microannuli caused by lack of bonding at the interfaces with casing and/or rock.

Research is being conducted on a CO2-resistant cement formulation. It was concluded that sound cement design is required, both for the placement and post-placement phases.

Selecting Sites for Geological Sequestration: Wellbore Integrity and Other Criteria Jason Heath, New Mexico Institute of Mining and Technology

The presenter, representing the Southwest Carbon Sequestration Partnership, described the efforts of the Partnership regarding selection of sites for geological sequestration. One of the key aspects for site selection is the identification of the best sink for each CO2 source.The presenter provided an example of the well integrity analysis at a test site, the Aneth Unit in southern Utah, where well construction deficiencies may potentially affect a pilot test of CO2 injection.
Analysis of well construction deficiencies included:
• Calculation of the top of cement,
• Temperature and cement bond logs, and
• Information on the depth of surface or intermediate casing.
Wells vulnerable to interformational migration of fluids were identified by the screening analysis described above. However, no monitoring has been performed in wells identified as vulnerable.


Well Construction
• Industry has developed recommended practices and protocols for well
construction. However, much of the research upon which the protocols are based
is confidential.
• Experience from EOR and acid gas operations provides a good working basis for
well construction.
• Pilot tests with real-world volumes of CO2 are needed.
• Performance-based construction standards may be appropriate.
Research Need: Development of lower cost materials that perform as well as high-cost materials.

Casing
• Abandonment procedures may need to be more stringent for geological
sequestration.
• Casing specifications depend on possible impurities, formation brine, pressure,
temperature, and operational conditions.
• Casing options include chrome tubing, expandable tubing, titanium casing,
fiberglass casing, and inhibited packer fluid for additional protection.
Research Need: Study the impacts of injection at varying depths.
Cementing
• Cement specifications depend on CO2 impurities; formation brine; and pressure,
temperature, and operational conditions.
• Cement should run the entire length of the wellbore.
Research Need: Alternative (non-Portland) cements.

The research needs determined from this group primarily centered on a review of
laboratory, field, and modeling studies concerning:

• Cement-related microannuli self-enhancing (enlarging) vs. self-healing (sealing),
that have been conducted by the industry,
• Impact of CO2 phase changes on mechanical integrity testing of wells,
• Impact of injectate impurities on the mechanical integrity of wells,
• MIT failure rates for new vs old wells,
• The phenomenon of a cold injection fluid opening up or enlarging gaps within the well system,
• Impact of large temperature differentials between injectate and well system/formation on
pressure tests,
• Monitoring methods/MITs that could detect rates and volumes of fluid movement along the
casing, and
• Time frames of MI changes and necessary MIT frequency.


Mr. Kobelski noted that EPA is currently assessing options for a management framework for
CO2 injection for the purposes of GS. GS presents many technical challenges that go beyond
those associated with CO2 injection for enhanced oil and gas recovery (EOR/EGR). For
example, GS will involve a variety of geologic settings apart from oil and gas reservoirs (e.g.,
saline aquifers and unmineable coal seams). In addition, the CO2 from coal-fired power plants will contain impurities (i.e., sulfur and nitrogen oxides, and metals such as mercury) that are not typically found in the CO2 used in EOR/EGR operations, and GS will involve significantly greater volumes and longer storage times.



Schlumberger Carbon Services - Schlumberger Public
CO2 reaction effects on well integrity
• Carbonation
• Matrix reacts: Portlandite/CSH → Calcite
•Water release
• At an early stage, may affect marginally matrix permeability (10-4→10-3 mD)
• May lead to mechanical instability (Calcite molar volume increase) •
• ¾” in 7-10 months, 1 m in 2000 years
•CO2 diffusion in water: ¾” in 3 days, 1 m in 20 years
• Leaching
• Strong dependency on local Ca2+ concentration gradient
• Cement effectively dissolves •


Cement sheath defects – effects on scale
• Fluid flow vs. matrix diffusion
• Preferential path of fluid flow bridges the scales
• Issue not limited to CO2: 15%-20% of wells may show hydraulic communication to surface
• Carbonation healing/plugging may be effective only at small scales
• Karst
• Positive feedback effect from enhanced leaching on defect walls

Assuring cement integrity over the well life
• Risk factors and scales
• Casing corrosion
• Leakage to shallower formations or to surface
• Multiple layers of risk mitigation
• Especially when repair is difficult
• Cement system selection and optimization
• Minimize or eliminate cement sheath defects
• Minimize or eliminate cement degradation
•Not necessarily cement reaction!


Well Construction: Potential Effects on Pilot Test
Potential impact of construction deficiencies:
Construction deficiencies could “provide a potential pathway for fluid migration between aquifers where there exists a differential in hydraulic head between aquifers.”
“Because the De Chelly aquifer hydraulic head exceeds the Navajo aquifer head in much of the Aneth Field area, saline water from the De Chelly Aquifer could potentially migrate upward into the Navajo aquifer through the partially cemented wellbores.”

How “risky” for CO2 migration are the wells that are vulnerable to communication between the Upper Paleozoic Aquifer and the Navajo Aquifer?
We think that the integrity and reactivity of the cement at/above/below the target reservoir (e.g., at the Paradox Formation in this case) is very important. If CO2 can leak through these “vulnerable” cement zones (e.g., the Paradox Formation here), then superjacent groundwater reservoirs may be impacted. Well cements must be sampled and characterized, and the conditions recorded and implemented in associated reservoir models for quantifying potential risk.

Notes about mechanical integrity testing:
The current portfolio of Regional Partnership pilot tests are small enough, in terms of injection rates, that special mechanical integrity testing is not necessary. Only “routine” mechanical testing is being done for these tests.

For Phase III, which will involve injection of over 1,000,000 tons/year in relatively few wells, plans are in place to include in situ tiltmeters and strain gauges (San Juan Basin). Water
injection pressure transient tests will be carried out prior to CO2 injection to characterize state-of-stress and response.

Bees, Balloons and CO2 Sequestration

Carbon sequestration buzz: Bees and balloons looking for leaks

URL http://cleantechnica.com/2009/07/21/carbon-sequestration-buz
z-bees-in-balloons-looking-for-leaks/

By Jeff Kart

You've heard of the canary in the coal mine as an indicator of a toxic
environment.

The U.S. Department of Energy is using bees and helium balloons to
make sure carbon dioxide is staying put in sequestration sites.

How? Researchers at the National Energy Technology Lab are using
chemical tracers to fingerprint CO2, then comparing it to pollen
collected by the bees.

“Researchers will determine if pollen collected by bees contains
measurable quantities of tracer or if bees bring back tracer from
direct contact with foliage. They will use balloons to determine
atmospheric variations in tracer content to assess the effectiveness
of CO2 storage sites,” the DOE reports:
http://www.ornl.gov/info/news/pulse/no291/feature.shtml

The agency is working with researchers from Michigan State University,
which by the way, makes its own honey.

Michigan is home to a carbon sequestration test site in Gaylord, part
of a larger project called the Midwest Regional Carbon Sequestration
Partnership.