Utah Admin. Code R649-3-39 - Hydraulic Fracturing
1. Chemical
disclosure.
1.1. The amount and type of
chemicals used in a hydraulic fracturing operation shall be reported to
www.fracfocus.org within 60 days of hydraulic fracturing completion for public
disclosure.
2. Wellbore
integrity.
2.1. The operator shall comply
with Section R649-3-8, Casing Program.
2.1.1. The method of cementing casing in the
hole shall be by pump and plug method, displacement method, or other method
approved by the division.
2.1.2.
When drilling in wildcat territory or in any field where high pressures are
probable, the conductor and surface strings of casing must be cemented
throughout their lengths, unless another procedure is authorized or prescribed
by the division, and any subsequent strings of casing must be securely
anchored.
2.1.3. In areas where the
pressures and formations to be encountered during drilling are known,
sufficient surface casing shall be run to:
2.1.3.1. Reach a depth below any known or
reasonably estimated, utilizable, domestic, fresh water levels.
2.1.3.2. Prevent blowouts or uncontrolled
flows.
2.1.4. The casing
program adopted must be planned to protect any potential oil or gas horizons
penetrated during drilling from infiltration of waters from other sources and
to prevent the migration of oil, gas, or water from one horizon to
another.
2.2. The
operator shall comply with Section
R649-3-9, Protection of Upper
Productive Strata.
2.2.1. No well shall be
deepened for the purpose of producing oil or gas from a lower stratum until any
upper productive strata are protected, either permanently by casing and
cementing or temporarily through the use of tubing and packer, to the
satisfaction of the division.
2.2.2. In any well that appears to have
defective, poorly cemented, or corroded casing that will permit or may create
underground waste or may contaminate underground or surface fresh water, the
operator shall proceed with diligence to use the appropriate method and means
to eliminate such hazard of underground waste or contamination of fresh water.
If such hazard cannot be eliminated, the well shall be properly plugged and
abandoned.
2.2.3. Natural gas that
is encountered in substantial quantities in any section of a drilled hole above
the ultimate objective shall be shut off with reasonable diligence, either by
mudding, casing or other approved method, and shall be confined to its original
source to the satisfaction of the division.
2.3. The operator shall comply with
R649-3-13, Casing Tests.
2.3.1. In order to determine the integrity of
the casing string set in the well, the operator shall, unless otherwise
requested by the division, perform a pressure test of the casing to the
pressures specified under R649-3-7.4 before drilling out of any casing string,
suspending drilling operations, or completing the well.
2.4. The operator shall comply with
R649-3-6, Drilling Operations.
2.4.1. Drilling operations shall be conducted
according to the drilling program submitted on the original APD and as approved
by the division. Any change of plans to the original drilling program shall be
submitted to the division by using Form 9, Sundry Notices and Reports on Wells
and shall receive division approval prior to implementation. A change of plans
necessary because of emergency conditions may be implemented without division
approval. The operator shall provide the division with verbal notice of the
emergency change within 24 hours and written notice within five days.
2.4.2. An operator of a drilling well as
designated in R649-2-4 shall comply with
reporting requirements as follows:
2.4.2.1.
The spudding in of a well shall be reported to the division within 24 hours.
The report should include the well name and number, drilling contractor, rig
number and type, spud date and time, the date that continuous drilling will
commence, the name of the person reporting the spud, and a contact telephone
number.
2.4.2.2. The operator shall
file Form 6, Entity Action Form with the division within five working days of
spudding in a well. The division will assign the well an entity number that
will identify the well on the operator's monthly oil and gas production and
disposition reports.
2.4.2.3. The
operator shall notify the division 24 hours in advance of any testing to be
performed on the blowout preventer equipment on a well.
2.4.2.4. The operator shall submit a monthly
status report for each drilling well on Form 9, Sundry Notices and Reports on
Wells. The report should include the well depth and a description of the
operations conducted on the well during the month. The report shall be
submitted no later than the fifth day of the following calendar month until
such time as the well is completed and the well completion report is
filed.
2.4.2.5 The operator shall
notify the division 24 hours in advance of any casing tests performed in
accordance with R649-3-13.
2.4.2.6. The operator shall report to the
division any fresh water sand encountered during drilling on Form 7, Report of
Water Encountered During Drilling. The report shall be filed with Form 8, Well
Completion or Recompletion Report and Log.
2.5. The operator shall comply with
R649-3-7, Well Control.
2.5.1. When drilling in wildcat territory,
the owner or operator shall take any reasonably necessary precautions for
keeping the well under control at any time and shall provide, at the time the
well is started, proper high pressure fittings and equipment. Any pressure
control equipment shall be maintained in good working condition at any
time.
2.5.2. In any proved areas,
the use of blowout prevention equipment "BOPE" shall be in accordance with the
established and approved practice in the area. Any pressure control equipment
shall be maintained in good working condition at any time.
2.5.3. Upon installation, any ram type BOPE
and related equipment, including casing, shall be tested to the lesser of the
full manufacturer's working pressure rating of the equipment, 70% of the
minimum internal yield pressure of any casing subject to test, or one psi/ft of
the last casing string depth. Annular type BOPE are to be tested in conformance
with the manufacturer's published recommendations. The operator shall maintain
records of such testing until the well is completed and will submit copies of
such tests to the division if required.
2.5.4. In addition to the initial pressure
tests, ram and annular type preventers shall be checked for physical operation
each trip. Any BOPE components, with the exception of an annular type blowout
preventer, shall be tested monthly to the lesser of 50% of the manufacturer's
rated pressure of the BOPE, the maximum anticipated pressure to be contained at
the surface, one psi/ft of the last casing string depth, or 70% of the minimum
internal yield pressure of any casing subject to test.
2.5.5. If a pressure seal in the assembly is
disassembled, a test of that seal shall be conducted prior to the resumption of
any drilling operation. A shell test of the affected seal shall be adequate. If
the affected seal is integral with the BOP stack, either pipe or blind ram,
necessitating a test plug to be set in order to test the seal, the division may
grant approval to proceed without testing the seal if necessary for prudent
operations.
2.5.6. Any tests of
BOPE shall be noted on the driller's log, IADC report book, or equivalent and
shall be available for examination by the director or an authorized agent
during routine inspections.
2.5.7.
BOPE used in possible or probable hydrogen sulfide or sour gas formations shall
be suitable for use in such areas.
2.6. The operator shall comply with
R649-3-23, Well Workover and
Recompletion.
2.6.1. Requests for approval of
a notice of intention to perform a workover or recompletion shall be filed by
an operator with the division on Form 9, Sundry Notices and Reports on Wells,
or if the operation includes substantial redrilling, deepening, or plugging
back of an existing well, on Form 3, Application for Permit to Drill, Deepen or
Plug Back.
2.6.2. The division
shall review the proposed workover or recompletion for conformance with the Oil
and Gas Conservation General Rules and advise the operator of its decision and
any necessary conditions of approval.
2.6.3. Recompletions shall be conducted in a
manner to protect the original completion interval(s) and any other known
productive intervals.
2.6.4. The
same tests and reports are required for any well recompletion as are required
following an original well completion.
2.6.5. The applicant shall file a subsequent
report of workover on Form 9, Sundry Notices and Reports, or a subsequent
report of recompletion on Form 8, Well Completion or Recompletion Report and
Log, within 30 days after completing the workover or recompletion
operations.
3.
Management of flowback water and surface protection.
3.1. The operator shall comply with
R649-3-15, Pollution and Surface
Damage Control.
3.1.1. The operator shall
take any reasonable precautions to avoid polluting lands, streams, reservoirs,
natural drainage ways, and underground water.
3.1.1.1. The owner or operator shall carry on
any operations and maintain the property at any time in a safe and workmanlike
manner having due regard for the preservation and conservation of the property
and for the health and safety of employees and people residing in close
proximity to those operations.
3.1.1.2. At a minimum, the owner or operator
shall:
3.1.1.2.1. Take reasonable steps to
prevent and shall remove accumulations of oil or other materials deemed to be
fire hazards from the vicinity of well locations, lease tanks and
pits.
3.1.1.2.2. Remove from the
property or store in an orderly manner, any scrap or other materials not in
use.
3.1.1.2.3. Provide secure
workmanlike storage for chemical containers, barrels, solvents, hydraulic
fluid, and other non-exempt materials.
3.1.1.2.4. Maintain tanks in a workmanlike
manner that will preclude leakage and provide for any applicable safety
measures, and construct berms of sufficient height and width to contain the
quantity of the largest tank at the storage facility.
3.1.1.2.4.1. The use of crude or produced
water storage tanks without tops is strictly prohibited except during well
testing operations.
3.1.1.2.5. Catch leaks and drips, contain
spills, and cleanup promptly.
3.1.1.2.6. Waste reduction and recycling
should be practiced in order to help reduce disposal volumes.
3.1.1.2.7. Produced water, tank bottoms and
other miscellaneous waste should be disposed of in a manner that is in
compliance with these rules and other state, federal, or local regulations or
ordinances.
3.1.1.2.8. In general,
good housekeeping practices should be
used.
3.2. The operator shall comply with
R649-3-16, Reserve Pits and
Other On-site Pits.
3.2.1. Small onsite oil
field pits including, but not limited to, reserve pits, emergency pits,
workover and completion pits, storage pits, pipeline drip pits, and sumps shall
be located and constructed in such a manner as to contain fluids and not cause
pollution of waters and soils. They shall be located and constructed according
to the Division guidelines for onsite pits. See Ranking Criteria for Reserve
and Onsite Pit Liner Requirements, on the Oil, Gas and Mining web
page.
3.2.2. Reserve pit location
and construction requirements including liner requirements will be discussed at
the predrill site evaluation. Special stipulations concerning the reserve pit
will be included as part of the Division's approval to drill.
3.2.3. Following drilling and completion of
the well the reserve pit shall be closed within one year, unless permission is
granted by the Division for a longer period.
3.2.4. Pit contents shall meet the Division's
Cleanup Levels (guidance document for numeric clean-up levels) or background
levels prior to burial.
3.2.5. The
contents may require treatment to reduce mobility or toxicity in order to meet
cleanup levels.
3.2.6. The
alternative to meeting cleanup levels would be transporting of material to an
appropriate disposal facility.
3.3. The operator shall comply with
R649-9-2, General Waste
Management.
3.3.1. Wastes addressed by these
rules are E and P Wastes that are exempt from the RCRA hazardous waste
management requirements.
3.3.1.1. Before
using a commercial disposal facility the operator may contact the Division to
verify the status of the facility. The Division regularly updates this
information on the Division of Oil, Gas and Mining web site.
3.3.1.2. Each site or facility used for
disposal must be permitted and in good standing with the
division.
3.3.2.
Reduction of the amount of material generated that must be disposed of is the
preferred practice.
3.3.2.1. Recycling should
be used whenever possible and practical.
3.3.2.2. In general, good housekeeping
practices shall be used.
3.3.2.3.
Operators shall catch leaks, drips, contain spills, and cleanup
promptly.
3.3.3. The
method of disposal used shall be compatible with the waste that is the subject
of disposal.
3.3.3.1. RCRA exempt waste shall
not be mixed with nonexempt waste.
3.3.4. Every operator shall file an Annual
Waste Management Plan by January 15 of each year to account for the proper
disposition of produced water and other E and P Wastes.
3.3.4.1. If changes are made to the plan
during the year, then the operator shall notify the division in writing of this
change.
3.3.4.2. This plan will
include the type and estimated annual volume of wastes that will be or have
been generated.
3.3.4.3. The
disposal facilities private or to be used for disposal,
3.3.4.4. The description of any waste
reduction or minimization procedures.
3.3.4.5. Any onsite disposal/treatment
methods or programs to be implemented by the
operator.
3.4.
The operator shall comply with
R649-5-1, Requirements for
Injection of Fluids Into Reservoirs.
3.4.1.
Operations to increase ultimate recovery, such as cycling of gas, the
maintenance of pressure, the introduction of gas, water or other substances
into a reservoir for the purpose of secondary or other enhanced recovery or for
storage and the injection of water into any formation for the purpose of water
disposal shall be permitted only by order of the board after notice and
hearing.
3.4.2. A petition for
authority for the injection of gas, liquefied petroleum gas, air, water, or any
other medium into any formation for any reason, including but not necessarily
limited to the establishment of or the expansion of waterflood projects,
enhanced recovery projects, and pressure maintenance projects shall contain:
3.4.2.1. The name and address of the operator
of the project.
3.4.2.2. A plat
showing the area involved and identifying any wells, including any proposed
injection wells, in the project area and within one-half mile radius of the
project area.
3.4.2.3. A full
description of the particular operation for which approval is
requested.
3.4.2.4. A description
of the pools from which the identified wells are producing or have
produced.
3.4.2.5. The names,
description and depth of the pool or pools to be affected.
3.4.2.6. A copy of a log of a representative
well completed in the pool.
3.4.2.7. A statement as to the type of fluid
to be used for injection, its source and the estimated amounts to be injected
daily.
3.4.2.8. A list of any
operators or owners and surface owners within a one-half mile radius of the
proposed project.
3.4.2.9. An
affidavit certifying that said operators or owners and surface owners within a
one-half mile radius have been provided a copy of the petition for
injection.
3.4.2.10. Any additional
information the board may determine is necessary to adequately review the
petition.
3.4.3.
Applications as required by
R649-5-2 for injection wells
that are located within the project area, may be submitted for board
consideration and approval with the request for authorization of the recovery
project.
3.4.4. Established
recovery projects may be expanded and additional wells placed on injection only
upon authority from the board after notice and hearing or by administrative
approval.
3.4.5. If the proposed
injection interval can be classified as an USDW, approval of the project is
subject to the requirements of
R649-5-4.
3.5. The operator shall comply with
R649-5-2, Requirements for Class
II Injection Wells Including Water Disposal, Storage and Enhanced Recovery
Wells.
3.5.1. Injection wells shall be
completed, equipped, operated, and maintained in a manner that will prevent
pollution and damage to any USDW, or other resources and will confine injected
fluids to the interval approved.
3.5.2. The application for an injection well
shall include a properly completed UIC Form 1 and the following:
3.5.2.1. A plat showing the location of the
injection well, any abandoned or active wells within a one- half mile radius of
the proposed well, and the surface owner and the operator of any lands or
producing leases, respectively, within a one-half mile radius of the proposed
injection well.
3.5.2.2. Copies of
electrical or radioactive logs, including gamma ray logs, for the proposed well
run prior to the installation of casing and indicating resistivity, spontaneous
potential, caliper, and porosity.
3.5.2.3. A copy of a cement bond or
comparable log run for the proposed injection well after casing was set and
cemented.
3.5.2.4. Copies of logs
already on file with the division should be referenced, but need not be
refiled.
3.5.2.5. A description of
the casing or proposed casing program of the injection well and of the proposed
method for testing the casing before use of the well.
3.5.2.6. A statement as to the type of fluid
to be used for injection, its source and estimated amounts to be injected
daily.
3.5.2.7. Standard laboratory
analyses of:
3.5.2.7.1. The fluid to be
injected,
3.5.2.7.2. The fluid in
the formation into which the fluid is being injected, and
3.5.2.7.3. The compatibility of the
fluids.
3.5.2.8. The
proposed average and maximum injection pressures.
3.5.2.9. Evidence and data to support a
finding that the proposed injection well will not initiate fractures through
the overlying strata or a confining interval that could enable the injected
fluid or formation fluid to enter any fresh water strata.
3.5.2.10. Appropriate geological data on the
injection interval with confining beds clearly labeled,
3.5.2.10.1. Nearby Underground Sources of
Drinking Water, including the geologic formation name,
3.5.2.10.2. Lithologic descriptions,
thicknesses, depths, water quality, and lateral extent;
3.5.2.10.3. Information relative to geologic
structure near the proposed well that may effect the conveyance or storage of
the injected fluids.
3.5.2.11. A review of the mechanical
condition of each well within a one-half mile radius of the proposed injection
well to assure that no conduit exists that could enable fluids to migrate up or
down the wellbore and enter improper intervals.
3.5.2.12. An affidavit certifying that a copy
of the application has been provided to any operators, owners, and surface
owners within a one-half mile radius of the proposed injection well.
3.5.2.13. Any other additional information
that the board or division may determine is necessary to adequately review the
application.
3.5.3.
Applications for injection wells that are within a recovery project area will
be considered for approval:
3.5.3.1. Pursuant
to R649-5-1-3.
3.5.3.2. Subsequent
to board approval of a recovery project pursuant to
R649-5-1-1.
3.5.4.
Approval of an injection well is subject to the requirements of
R649-5-4, if the proposed
injection interval can be classified as an USDW.
3.6. The operator shall comply with
R649-5-3, Noticing and Approval
of Injection Wells.
3.6.1. Applications for
injection wells submitted pursuant to R649-5-1-3 shall be noticed in
conformance with the procedural rules of the board as part of the hearing for
the recovery project. Any person desiring to object to approval of such an
application for an injection well shall file the objection in conformance with
the procedural rules of the board.
3.6.2. The receipt of a complete and
technically adequate application, other than an application submitted pursuant
to R649-5-3-1, shall be considered as a request for agency action by the
Division and shall be published in a daily newspaper of general circulation in
the city and county of Salt Lake and in a newspaper of general circulation in
the county where the proposed well is located. A copy of the notice of agency
action shall also be sent to any parties including government agencies. The
notice of agency action shall contain at least the following information:
3.6.2.1. The applicant's name, business
address, and telephone number.
3.6.2.2. The location of the proposed
well.
3.6.2.3. A description of
proposed operation.
3.6.3. If no written objection to the
application for administrative approval of an injection well is received by the
division within 15 days after publication of the notice of agency action, or an
aquifer exemption is not required in accordance with
R649-5-4, and a board hearing is
not otherwise required, the application may be considered and approved
administratively.
3.6.4. If a
written objection to an application for administrative approval of an injection
well is received by the division within 15 days after publication of the notice
of application, or if a hearing is required by these rules or deemed advisable
by the director, the application shall be set for notice and hearing by the
board.
3.6.5. The director shall
have the authority to grant an exception to the hearing requirements of
R649-5-1.1 for conversion to injection of additional wells that constitute a
modification or expansion of an authorized project provided that any such well
is necessary to develop or maintain thorough and efficient recovery operations
for any authorized project and provided that no objection is received pursuant
to R649-5-3-3.
3.6.6. The director
shall have authority to grant an exception to the hearing requirements of
R649-5-1-1 for water disposal wells provided disposal is into a formation or
interval that is not currently nor anticipated to be an underground source of
drinking water and provided that no objection is received pursuant to
R649-5-3-3.
3.7. The
operator shall comply with
R649-5-4, Aquifer Exemption.
3.7.1. The board may, after notice and
hearing and subject to the EPA approval, authorize the exemption of certain
aquifers from classification as an USDW based upon the following findings:
3.7.1.1. The aquifer does not currently serve
as a source of drinking water.
3.7.1.2. The aquifer cannot now and will not
in the future serve as a source of drinking water for any of the following
reasons:
3.7.1.2.1. The aquifer is mineral,
hydrocarbon or geothermal energy producing, or it can be demonstrated by the
applicant as part of a permit application for a Class II well operation, to
contain minerals or hydrocarbons that, considering their quantity and location,
are expected to be commercially producible.
3.7.1.2.2. The aquifer is situated at a depth
or location that makes recovery of water for drinking water purposes
economically or technologically impractical.
3.7.1.2.3. The aquifer is contaminated to the
extent that it would be economically or technologically impractical to render
water from the aquifer fit for human consumption.
3.7.1.2.4. The aquifer is located above a
Class III well mining area subject to subsidence or catastrophic
collapse.
3.7.1.3. The
total dissolved solids content of the water from the aquifer is more than 3,000
and less than 10,000 mg/l, and the aquifer is not reasonably expected to be
used as a source of fresh or potable water.
3.7.2. Interested parties desiring to have an
aquifer exempted from classification as a USDW, shall submit to the division an
application that includes sufficient data to justify the proposal. The division
shall consider the application and if appropriate, will advise the applicant to
submit a request to the board for an aquifer exemption.
3.8. The operator shall comply with
R649-5-5, Testing and Monitoring
of Injection Wells.
3.8.1. Before operating a
new injection well, the casing shall be tested to a pressure not less than the
maximum authorized injection pressure, or to a pressure of 300 psi, whichever
is greater.
3.8.2. Before operating
an existing well newly converted to an injection well, the casing outside the
tubing shall be tested to a pressure not less than the maximum authorized
injection pressure, or to a pressure of 1,000 psi, whichever is lesser,
provided that each well shall be tested to a minimum pressure of 300
psi.
3.8.3. In order to demonstrate
continuing mechanical integrity after commencement of injection operations, any
injection wells shall be pressure tested or monitored as follows:
3.8.3.1. Pressure Test. The casing-tubing
annulus above the packer shall be pressure tested not less than once each five
years to a pressure equal to the maximum authorized injection pressure or to a
pressure of 1,000 psi, whichever is lesser, provided that no test pressure
shall be less than 300 psi. A report documenting the test results shall be
submitted to the division.
3.8.3.2.
Monitoring. If approved by the director, and in lieu of the pressure testing
requirement, the operator may monitor the pressure of the casing-tubing annulus
monthly during actual injection operations and report the results to the
division.
3.8.3.3. Other test
procedures or devices such as tracer surveys, temperature logs or noise logs
may be required by the division on a case-by-case basis.
3.8.3.4. The operator shall sample and
analyze the fluids injected in each disposal well or enhanced recovery project
at sufficiently frequent time intervals to yield data representative of fluid
characteristics, and no less frequently than every year.
3.8.3.5. The operator shall submit a copy of
the fluid analysis to the division with the Annual Fluid Injection Report, UIC
Form 4.
3.9.
The operator shall comply with
R649-5-6, Duration of Approval
for Injection Wells.
3.9.1. Approvals or
orders authorizing injection wells shall be valid for the life of the well,
unless revoked by the board for just cause, after notice and hearing.
3.9.2. An approval may be administratively
amended if:
3.9.2.1. There is a substantial
change of conditions in the injection well operation.
3.9.2.2. There are substantial changes to the
information originally furnished.
3.9.2.3. Information as to the permitted
operation indicates that an USDW is no longer being
protected.
Notes
State regulations are updated quarterly; we currently have two versions available. Below is a comparison between our most recent version and the prior quarterly release. More comparison features will be added as we have more versions to compare.
No prior version found.