Texas Administrative Code › Title 16 - ECONOMIC REGULATION › Part 1 - RAILROAD COMMISSION OF TEXAS › Chapter 5 - CARBON DIOXIDE (CO2) › Subchapter C - CERTIFICATION OF GEOLOGIC STORAGE OF ANTHROPOGENIC CARBON DIOXIDE (CO2) INCIDENTAL TO ENHANCED RECOVERY OF OIL, GAS, OR GEOTHERMAL RESOURCES › Section 5.305 - Monitoring, Sampling, and Testing Plan

Current through Reg. 49, No. 28; July 12, 2024
An operator registering for certification under this
					 subchapter must submit a monitoring, sampling, and testing plan to verify
					 geologic storage of the anthropogenic CO2 incidental to
					 enhanced recovery.
(1) The monitoring,
				  sampling, and testing plan must include the following:
(A) an analysis of the
				  CO2 stream at a frequency sufficient to yield data
				  representative of its chemical and physical characteristics;
(B) installation of continuous monitoring
				  devices (including digital devices to capture periodic data) to monitor
				  injection pressure, rate of injected CO2, and volume of
				  injected CO2. The operator shall perform monitoring of
				  daily pressure on the annulus between the tubing and the long string casing by
				  use of either continuous monitoring device or by using a pressure gauge with a
				  rupture disk with automated alarm to signal pressures outside of the permitted
				  operating range. The operator may remove these devices during well workovers
				  but must reinstall them at the completion of the workover; the Commission may
				  approve alternative methods of monitoring the annulus between the tubing and
				  long string casing when considering injection well construction, operating
				  pressures, and the oil and gas reservoir;
(C) demonstration of external mechanical
				  integrity by one of the following, or another approved, method:
				  oxygen-activation log survey, temperature log, noise log, or casing inspection
				  log if the operator detects a problem, or once every five years, until the well
				  is permanently plugged;
(D)
				  corrosion monitoring of the well materials that will come into contact with
				  water for loss of mass, thickness, cracking, pitting, and other signs of
				  corrosion. The operator shall perform corrosion monitoring at one or more
				  designated representative test sites typical of the enhanced recovery facility
				  initially and quarterly, and the operator shall report quarterly, but may be
				  modified to a less frequent schedule as approved by the Commission, based on
				  the construction materials, operating conditions, and monitoring history that
				  show the well components meet minimum standards and performance by:
(i) analyzing coupons of the well
				  construction materials placed in contact with the CO2
				  stream; or
(ii) routing the
				  CO2 stream through a closed loop constructed with the
				  material used in the well and inspecting the material in the loop; or
(iii) using an alternative method, materials,
				  or time period approved by the Commission;
(E) annual monitoring of the injection zone
				  pressure in the productive reservoir, including at a minimum, at least once
				  every five years, a shut-down of each injection well for a time sufficient to
				  estimate reservoir pressure at the site;
(F) monitoring wells as needed for continuous
				  monitoring for pressure changes in an appropriately porous and permeable
				  formation above the confining zone. For each well installed, the operator must
				  set forth the specified frequency of sampling the interval and analyzing the
				  constituents as specified in the plan;
(G) periodic monitoring of the useable
				  quality water strata overlying the productive reservoir to monitor for changes
				  in quality due to CO2 injection; and
(H) the use of indirect, geophysical
				  techniques to determine the position of the CO2 fluid
				  front, or to provide other site-specific data.