co 2 sequestration
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DESCRIPTIONCO 2 Sequestration. Dave Hill. 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) - PowerPoint PPT Presentation
CO2 Sequestration Dave Hill1RAILROAD COMMISSION OF TEXASOverview2Class 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.
Federal Overview3Class 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.
The Various Means of CCS
Senate Bill 1387 (SB 1387), 2009SB1387: 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). 5
Anthropogenic Carbon Dioxide6SB 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.
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 7
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
Notice and Hearing95.204 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.
Fees, Financial Responsibility, and Financial Assurance105.205 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.
Permit Standards115.206 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.
Permit Standards125.206 also includes
Implementation of plans (previously listed)
Requirement of a Letter from RRC Groundwater Advisory Unit stating that the facility will not injure USDWs.
Reporting and Record Keeping135.207 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
Chapter 5: NEWEST REGULATIONSAssociated with EOR/EGR 14PURPOSE: 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
Chapter 5: NEWEST REGULATIONSAssociated 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
Chapter 5: NEWEST REGULATIONSAssociated with EOR/EGR 16Monitoring, 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
Chapter 5: NEWEST REGULATIONSAssociated with EOR/EGR 17Monitoring, 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.
Overview (Revisited)18Class 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.
Sources of CO2 and Users 19
CO2 EOR Sources20
SACROC Eastern Edge of Permian Basin21
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)
SACROC Well Map22
SACROC Previous CO2 Injection23
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
BEG and TWDB Water Well Data at SACROC24
Surface geology from BEG Big Spring and Lubbock GAT sheetsGeologic unitsQ Quaternary undifferentiated
P-Eog Paleocene-Eocene Ogallala
TrD Triassic Dockum
P Permian undifferentiated
Cross Section 25
(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 Austinand Brian McPherson, New Mexico Tech and University of Utah
26Temporal Trends of all TWDB & BEG Data
27Temporal Trends of all TWDB & BEG Data
SACROC AREA WATER QUALITY 2836 of 60 wells completed in both Ogallala and Dockum Santa Rosa water- bearing units; 17 wells inside and 19 wells outside SACROC; highest data
Historic CO2 Sales29
Current Situation CO2 EOR Projects30
Current Situation CO2 EOR Production31
32Injection/Disposal Well Permit Testing and Monitoring Seminar Manual http://www.rrc.state.tx.us/forms/publications/HTML/pmt-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.
33Administrative 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.
34Post PermittingAnnual 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. Mechanical integrity test (MIT) (Form H-5): - Verify that the well wont leak before injection. MITs must be performed periodically for the life of the permit. 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.
Facilities and Water WellsYearDrilling PermitsActive WellsInjection WellsWater Well Complaints*200416,912242,00030,90044200519,548246,00031,30038200622,328249,00030,60061200723,916250,00030,60042200828,786263,00030,60048200915,917274,00030,80047201022,535281,00031,40043201128,300281,00031,50083201227,359284,00033,00017201326,129288,00033,5003835* 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.
The End 36
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