Transcript Document

RAILROAD COMMISSION OF TEXAS
CO2 Sequestration
Dave Hill
1
Overview
• Class I wells
- Hazardous wastes and non-hazardous
industrial or municipal wastes are injected
beneath the lowermost underground source
of drinking water (USDW).
• Class II wells (second half of this talk)
- Enhanced oil recovery (EOR) injection and
disposal of oil and gas wastes.
• Class III wells
- Associated with solution mining.
2
Federal Overview
• Class IV wells
- Shallow injection of treated hazardous wastes
and are banned except when used as part of
authorized groundwater remediation projects.
• Class V wells
- Shallow injection of non-hazardous fluids not
covered by Class I wells, and experimental
wells.
• Class VI wells
- Recently created by EPA, are associated with
CO2 capture and storage (CCS) activities. 3
The Various Means of CCS
4
Senate Bill 1387 (SB 1387), 2009
• SB1387: In 2009, the Texas Legislature passed,
and the governor signed a bill, “relating to the
capture, injection, sequestration, or geologic
storage of carbon dioxide”.
-Response to draft of federal Class VI rules
-Underground Injection Control (UIC) part
of the Federal Safe Drinking Water Act
(SDWA).
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Anthropogenic Carbon Dioxide
• SB 1387 in large measure deals with
anthropogenic CO2 which is “ carbon dioxide
that would otherwise be released to the
atmosphere…”.
- Includes CO2 from gas processing plant or an
industrial emissions source.
- Excludes naturally occurring CO2 recaptured,
recycled, or reinjected as part of enhanced
oil recovery (EOR) operations.
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16 TAC Chapter 5: RRC CO2 CCS REGS
 Site characterization
 AOR and corrective action
 Well construction/Plugging
 Mechanical integrity/Monitoring
 Emergency response
 Financial Security
 Post-injection facility care
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Plans Required
§5.203 (f): Logging and Sampling Before Injection
 §5.203 (h) Mechanical Integrity Testing
 §5.203 (i) Facility operating plan.
 §5.203 (j) Monitoring after Initiating Operations
 §5.203 (k) P & A of Injection & Monitoring Wells.
 §5.203 (l) Emergency and Remedial response.
 §5.203 (m) Post Injection Care and Closure
8
Notice and Hearing
• §5.204 includes notice and hearing
requirements.
- Notice by local publication
- Local and public placement of a copy
of the application
- Criteria for persons to be notified
- Requirements for a hearing.
9
Fees, Financial Responsibility,
and Financial Assurance
• §5.205 includes description of Fees,
Financial Responsibility, and Financial
Assurance requirements.
- Fees to be paid for applications
- Financial responsibility verification
- Financial assurance criteria regarding
operations and phases of the facility.
10
Permit Standards
• §5.206 states RRC may issue a permit if:
No endangerment/injury to oil, gas, other
minerals,
Water protected from CO2 migration or
displaced fluids,
No endangerment/injury to human
health/safety,
Reservoir suitable for preventing CO2
escape/migration,
Applicant meets statutory and regulatory
requirements.
11
Permit Standards
• §5.206 also includes
Implementation of plans (previously listed)
Requirement of a Letter from RRC
Groundwater Advisory Unit stating that the
facility will not injure USDW’s.
12
Reporting and Record Keeping
• §5.207 includes reporting and record keeping
requirements.
- Test records
- Operating reports
- Reporting frequency depends on the type
of information reported. This ranges
from 24 hours to annual reporting
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Chapter 5: NEWEST REGULATIONS
Associated with EOR/EGR
PURPOSE: Provide for certification of CCS of CO2
incidental to enhanced recovery operations for
which:
 there is a reasonable expectation of more
than insignificant future production volumes or
rates as a result of the injection of
anthropogenic CO2 ; and
 operating pressures no higher than
reasonably necessary for enhanced recovery
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Chapter 5: NEWEST REGULATIONS
Associated with EOR/EGR
Registration for Certification
Requires registration of enhanced recovery
facility for which the operator proposes to
document CCS of anthropogenic CO2
incidental to enhanced recovery
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Chapter 5: NEWEST REGULATIONS
Associated with EOR/EGR
Monitoring, Sampling and Testing Plan:
This is required for determination of the quantities
of anthropogenic CO2 permanently stored within
the enhanced recovery reservoir. For this, there
are two options.
§5.305 (2) is one of them. This includes “mass
balancing or actual system modeling”
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Chapter 5: NEWEST REGULATIONS
Associated with EOR/EGR
Monitoring, Sampling and Testing Plan:
§5.305 (3) is the other option. The owner /
operator may submit to RRC, a copy of the same
information submitted to EPA under Subparts RR
or UU of 40 CFR Part 98, Mandatory Reporting of
Greenhouse Gases: Injection and Geologic
Sequestration of Carbon Dioxide.
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Overview (Revisited)
• Class I wells
- Hazardous wastes and non-hazardous
industrial or municipal wastes are injected
beneath the lowermost underground source
of drinking water (USDW).
• Class II wells
- Enhanced oil recovery (EOR) injection and
disposal of oil and gas wastes.
• Class III wells
- Associated with solution mining.
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Sources of CO2 and Users
19
CO2 EOR Sources
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SACROC – Eastern Edge of Permian Basin
Scurry Area Canyon Reef
Operators Committee
(SACROC) unitized oil field
• Ongoing CO2 injection since 1972
• Combined enhanced oil recovery
(EOR) with CO2 sequestration
• Depth to Pennsylvanian- Permian
reservoir ~6,500 ft
• Approximately 3900 miles of CO2
pipelines (Dooley et al)
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SACROC Well Map
22
SACROC Previous CO2 Injection
KM currently operates
SACROC and is
providing much
assistance with the
project

3 trillion standard cubic feet
(TCF) or 150 million metric tons
(MMt) CO2 injected for
enhanced oil recovery (EOR)
since 1972 by multiple field
operators (BEG, 1984; KM,
2008)

1.5 TCF (75 MMt) CO2
recovered as of October 1, 2008
(KM, 2008)

Southwest Partnership (SWP)
researchers are among first to
test if this CO2 is trapped in
reservoir zones or if it has
leaked into overlying strata
23
BEG and TWDB Water Well Data at SACROC
Geologic units
Surface geology from BEG Big Spring and Lubbock GAT sheets
Q–
Quaternary
undifferentiated
P-Eog –
Paleocene-Eocene
Ogallala
TrD –
Triassic Dockum
P–
Permian
undifferentiated
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Cross Section
(modified from Duffin and Benyon, 1992)
Rebecca C. Smyth, Bureau of Economic Geology, Gulf Coast Carbon Center,
Jackson School of Geosciences, The University of Texas at Austin
and
Brian McPherson, New Mexico Tech and University of Utah
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Temporal
Trends of all
TWDB & BEG Data
10000.0
HCO3-
Outside
SACROC
concnetration (mg/L)
1000.0
100.0
10.0
1930
1950
1970
year
1990
2010
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Temporal
Trends of all
TWDB & BEG Data
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SACROC AREA WATER QUALITY
36 of 60 wells completed in both Ogallala and Dockum Santa Rosa waterbearing units; 17 wells inside and 19 wells outside SACROC; highest data
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Historic CO2 Sales
Average Daily CO2 Sales - North America
4,000
3,500
Other
3,000
Dakota Gasification
MS/Gulf Coast
Rockies
Permian Basin
CO2 Sales (MMcfpd)
2,500
2,000
1,500
1,000
500
0
1983 1984 1985 1986 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011
Year
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Current Situation – CO2 EOR Projects
GROWTH OF WW, U.S. and PERMIAN BASIN
CO2 EOR PROJECTS
1992 - 2012
Worldwide Projects
U.S. Projects
Permian Basin Projects
160
120
100
80
60
40
20
2012
2010
2008
2006
2004
2002
2000
1998
1996
1994
0
1992
NO. OF PROJECTS
140
YEAR
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Current Situation – CO2 EOR Production
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Injection/Disposal Well Permit Testing and
Monitoring Seminar Manual
• http://www.rrc.state.tx.us/forms/publications/HTML/pm
t-outl.php#techrev
- I. Administrative Review Check non-technical filing requirements
- II. Attachments for new wells
- III. Transfer and Amendments
- IV. Technical Review Compliance with well construction,
operation, and injected fluid confinement requirements
- V. Permit Processing Stages of review
- VI. Protested Applications Stages for protested applications
- VII. Post Permitting Report requirements after the injection
permit is issued.
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Administrative Review – Basic
Filing requirements
1. Application Forms.
* Forms H-1 , and H-1A. (Injection into a Reservoir Productive
of Oil or Gas, Rule 46).
- A productive reservoir is one with past or current production
within a 2-mile radius of the proposed injection well.
* Form W-14 , (Injection Non-productive reservoir, Rule 9).
2. Fees. These fees are non-refundable.
a. $100 disposal permit application (Rule 9) filing fee (per
wellbore).
b. $500 injection permit application (Rule 46) filing fee (per
wellbore).
c. $375 (additional) for each exception request.
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Post Permitting
1. Annual Monitoring Report (Form H-10):
- Report Injection pressure and volumes unless
the well is actively producing and they file an annual
production status report (Form W-10 or G-10) instead.
2. Mechanical integrity test (MIT) (Form H-5):
- Verify that the well won’t leak before injection.
MITs must be performed periodically for the life of the
permit.
3. Completion report (Form W-2 or G-1):
- Within 30 days of conversion, document the
actual completion details of the well. Staff will review
form against the approved permit.
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Facilities and Water Wells
Year
Drilling
Permits
2004
16,912
242,000
30,900
44
2005
19,548
246,000
31,300
38
2006
22,328
249,000
30,600
61
2007
23,916
250,000
30,600
42
2008
28,786
263,000
30,600
48
2009
15,917
274,000
30,800
47
2010
22,535
281,000
31,400
43
2011
28,300
281,000
31,500
83
2012
27,359
284,000
33,000
17
2013
26,129
288,000
33,500
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Active Wells
Injection
Wells
Water Well
Complaints*
* The majority of these complaints are drought related. Many others involve one
time sampling events for oil and gas constituents, where lab data show no impact.
About two wells per year are confirmed to be attributable to Oil & Gas activities.
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The End
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Contact Info
http://www.rrc.state.tx.us/
[email protected] 512 463 3011
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