Current through February 27, 2024
(a) Before hydraulic fracturing, the operator
must submit an Application for Sundry Approvals (Form 10-403) under
20 AAC 25.280. Unless modified or
altered by pool rules established under
20 AAC 25.520, the application
must include
(1) an affidavit stating that all
owners, landowners, surface owners, and operators within a one-half mile radius
of the current or proposed wellbore trajectory have been provided a notice of
operations that is in compliance with the requirements of this paragraph; in
the notice of operations, the operator must
(A) state that upon request a complete copy of the application is
available from the operator; and
(B) include the operator contact information;
(2) a plat
(A) showing the well location;
(B) identifying each water well, if any. located within a one-half
mile radius of the well's surface location; and
(C) identifying for all well types
(i) each well penetration, if any, within one-half mile of the
current or proposed wellbore trajectory and fracturing interval; and
(ii) the source of information used in
identifying each well penetration;
(3) identification of each freshwater
aquifer, if any, within a one-half mile radius of the current or proposed
wellbore trajectory, the geological name of the freshwater aquifer, the
measured depth of the freshwater aquifer, and the true vertical depth of the
freshwater aquifer;
(4) a plan for
baseline water sampling of water wells before hydraulic fracturing, as follows:
(A) water sampling consists of collection of
baseline water data before hydraulic fracturing, within a one-half mile radius
of the current or proposed wellbore trajectory;
(B) the operator must detail the well
selection process for identifying wells to sample;
(C) if a surface owner denies permission for
baseline water sampling or for disclosure of the results, the operator
(i) must document the reasonable and
good-faith efforts taken to secure that permission; and
(ii) is not required to include the surface
owner in any sampling required under (j) of this section of water wells after
hydraulic fracturing;
(D)
sample parameters must include
(i)
pH;
(ii) alkalinity, measured as
the presence of total bicarbonate and carbonate, and expressed as parts per
million of calcium carbonate;
(iii) specific conductance;
(iv) the presence of bacteria that is iron-related,
sulfate-reducing, or slime-forming;
(v) arsenic;
(vi)
barium;
(vii)
bicarbonate;
(viii)
boron;
(ix) bromide;
(x) cadmium:
(xi) calcium;
(xii) chloride;
(xiii) chromium;
(xiv) fluoride;
(xv) hydroxide;
(xvi) iodide;
(xvii) iron;
(xviii) lithium;
(xix) magnesium;
(xx)
manganese;
(xxi) total nitrate and
nitrate, measured as the presence of nitrogen;
(xxii) phosphorus;
(xxiii) potassium;
(xxiv) radium, measured as the presence of combined radium-226 and
radium-228;
(xxv)
selenium;
(xxvi)
silicon;
(xxvii) sodium;
(xxviii) strontium;
(xxix) sulfate;
(xxx) total dissolved solids;
(xxxi) total petroleum hydrocarbons,
expressed as the results of the analyses made under (xxxii) - (xxxvi) of this
subparagraph;
(xxxii) benzene,
toluene, ethylbenzene, and total xylene isomers (BTEX); the Application for
Sundry Approvals (Form 10-403) must state whether the operator proposes to
measure those substances using the United States Environmental Protection
Agency's methods 5035, 8260B, or 8260C in Test Methods for Evaluating
Solid Waste, Physical/Chemical Methods (EPA publication SW-846). or an
alternate method proposed for commission approval as effective for measuring
those substances;
(xxxiii)
gasoline range organics (GRO); the Application for Sundry Approvals (Form
10-403) must state whether the operator proposes to measure those substances
using the United States Environmental Protection Agency's methods 5035, 8015C,
or 8015D in Test Methods for Evaluating Solid Waste, Physical/Chemical
Methods (EPA publication SW-846), method AK 101 in the Department of
Environmental Conservation's Underground Storage Tanks Procedures
Manual, or an alternate method proposed for commission approval as
effective for measuring those substances;
(xxxiv) diesel range organics (DRO); the Application for Sundry
Approvals (Form 10-403) must state whether the operator proposes to measure
those substances using the United States Environmental Protection Agency's
methods 8015C or 8015D in Test Methods for Evaluating Solid Waste,
Physical/Chemical Methods (EPA publication SW-846) with silica gel
cleanup, method AK 102 in the Department of Environmental Conservation's
Underground Storage Tanks Procedures Manual, or an alternate
method proposed for commission approval as effective for measuring those
substances;
(xxxv) polynuclear
aromatic hydrocarbons, including benzo(a)pyrene; and
(xxxvi) dissolved methane, dissolved ethane,
and dissolved propane: the Application for Sundry Approvals (Form 10-403) must
state whether the operator proposes to measure those substances using the
United States Environmental Protection Agency's Standard Operating
Procedure: Sample Preparation and Calculations for Dissolved Gas Analysis in
Water Samples Using a GC Headspace Equilibration Technique (EPA
publication RSK SOP 175. Revision No. 2) or an alternate method proposed for
commission approval as effective for measuring those
substances;
(E) the plan
must require documentation of odor, water color, sediment, bubbles,
effervescence, and other field observations;
(F) the plan must require that if free gas or a dissolved methane
concentration greater than 1.0 mg/l is detected in a water sample, the gas type
shall be determined by means of a gas compositional analysis and stable isotope
analysis of the methane; a stable isotope analysis must include an analysis of
carbon-12, carbon-13, hydrogen-1, and hydrogen-2 isotopes;
(G) the plan must require that the operator
notify the commission, the Department of Environmental Conservation, and the
surface owner within 24 hours if
(i) the test
results indicate thermogenic or a mixture of thermogenic and biogenic
gas;
(ii) the plan requires
multiple samples within a stated timeframe, and the methane concentration
increases by more than 5.0 mg/l between sampling periods;
(iii) the methane concentration is detected
at or above 10 mg/l; or
(iv) total
petroleum hydrocarbons as described in (D)(xxxi) of this paragraph, benzene,
toluene, ethylbenzene, xylene isomers, gasoline range organics. or diesel range
organics are detected;
(H) except as otherwise provided under this paragraph, the plan
must provide for the use of current applicable sample custody and collection
protocols and analytical methods that the Department of Environmental
Conservation or the United States Environmental Protection Agency (EPA) has
approved, or an alternate protocol or method proposed for commission approval
as effective for custody, collection, or analysis of a sample: the plan must
provide that analyses be performed by laboratories that maintain nationally
accredited programs;
(I) not later
than 90 days after a sample is collected, a copy of each test result,
analytical result, and sample location must be provided to the commission and
to the Department of Environmental Conservation in printed form and in an
electronic data deliverable format that is acceptable to the
commission;
(5) detailed
casing and cementing information;
(6) an assessment of each casing and
cementing operation performed to construct or repair the well; the assessment
must include sufficient supporting information, including cement evaluation
logs and other evaluation logs approved by the commission, to demonstrate that
(A) casing is cemented
(i) below the base of the lowermost freshwater aquifer;
and
(ii) in accordance with
20 AAC 25.030;
and
(B) each hydrocarbon
zone penetrated by the well is isolated;
(7) pressure test information if available
and plans to pressure-test the casings and tubing installed in the
well;
(8) accurate pressure
ratings and schematics for the wellbore, wellhead, BOPE, and treating
head;
(9) data for the fracturing
zone and confining zones, including
(A) a
lithologic description of each zone;
(B) the geological name of each zone;
(C) the measured depth and true vertical
depth of each zone;
(D) the
measured thickness and true vertical thickness of each zone; and
(E) the estimated fracture pressure for each
zone;
(10) the location,
the orientation, and a report on the mechanical condition of each well that may
transect the confining zones, and information sufficient to support a
determination that the well will not interfere with containment of the
hydraulic fracturing fluid within the one-half mile radius of the proposed
wellbore trajectory;
(11) the
location of, orientation of, and geological data for each known or suspected
fault or fracture that may transect the confining zones, and information
sufficient to support a determination that the known or suspected fault or
fracture will not interfere with containment of the hydraulic fracturing fluid
within the one-half mile radius of the proposed wellbore trajectory;
(12) a detailed copy of the proposed
hydraulic fracturing program; the proposed program must include the pumping
procedure by stage if applicable, with a chemical disclosure based on the total
amounts and volumes per well, including the
(A) estimated total volumes planned;
(B) trade name, generic name, and purpose of
each base fluid and additive to be used; the estimated or maximum rate or
concentration of each additive must be provided in appropriate measurement
units;
(C) chemical ingredient
name of, and the Chemical Abstracts Service (CAS) registry number assigned to,
each base fluid and additive to be used; the actual or maximum concentration of
each chemical ingredient in each base fluid and additive used must be provided
in percent by mass; the actual or maximum concentration of each chemical
ingredient in the hydraulic fracturing fluid must be provided in percent by
mass; freeze-protect fluids pumped before or after hydraulic fracturing may not
be included;
(D) estimated weight
or volume of each inert substance, including a proppant or other substance
injected;
(E) maximum anticipated
treating pressure and information sufficient to support a determination that
the well is appropriately constructed for the proposed hydraulic fracturing
program; and
(F) designed height
and length of each proposed fracture, including
(i) the calculated measured depth and true vertical depth of the
top of the fracture; and
(ii) a
description of each method and assumption used to determine designed fracture
height and length; and
(13) a detailed description of the plan for post-fracture wellbore
cleanup and fluid recovery through to production
operations.
(b) When
hydraulic fracturing is done through production casing or through intermediate
casing, the casing must be tested to 110 percent of the maximum anticipated
pressure differential to which the casing may be subjected. If the casing fails
the pressure test, the casing must be repaired or the operator must use a
fracturing string.
(c) When
hydraulic fracturing is done through a fracturing string, the fracturing string
must be
(1) stung into a liner or run on a
packer set at a measured depth of not less than 100 feet below the cement top
of the production casing or intermediate casing; and
(2) tested to not less than 110 percent of
the maximum anticipated pressure differential to which the fracturing string
may be subjected.
(d) A
pressure relief valve must be installed on the treating line between a pump and
the wellhead to limit the line pressure to the test pressure determined under
(a)(12)(E) of this section. The well must be equipped with a remotely
controlled shut-in device unless the operator requests and obtains a waiver
from the commission under (l) of this section.
(e) The placement of all hydraulic fracturing
fluids shall be confined to the approved formations during hydraulic
fracturing.
(f) If the surface
casing annulus is not open to atmospheric pressure, the surface casing
pressures shall be monitored with a gauge and pressure relief device while
hydraulic fracturing operations are in progress. The annular space between the
fracturing string and the intermediate or production casing must be
continuously monitored. The pressure in that annular space may not exceed the
pressure rating of the lowest rated component that would be exposed to pressure
if the fracturing string failed.
(g) During hydraulic fracturing operations, all annulus pressures
must be continuously monitored and recorded. If at any time during hydraulic
fracturing operations the annulus pressure increases more than 500 psig above
those anticipated increases caused by pressure or thermal transfer, the
operator shall
(1) notify the commission as
soon as practicable, but not later than 24 hours following the
incident;
(2) implement corrective
action or increased surveillance as the commission requires; and
(3) submit a Report of Sundry Well
Operations (Form 10-404) not later than 15 days after the incident; in the
report the operator shall give all details of the incident, including
corrective actions taken.
(h) Not later than 30 days after completion of hydraulic
fracturing operations, the operator shall file with the commission, on a Report
of Sundry Well Operations (Form 10-404), a complete record of the work
performed and the tests conducted, a summary of daily well operations as
described in 20 A AC 25.070(3), and a copy of the daily record required under
20 AAC 25.070(1).
As part of the tiling the operator shall include,
(1) for each hydraulic fracturing interval,
(A) the measured depth and true vertical
depth of each perforation or sleeve for the actual treated interval;
and
(B) the amount and type of
each base fluid and each additive pumped during each stage;
and
(2) for each
hydraulic fracturing treatment addressed in the Report of Sundry Well
Operations, the total amount and type of each base fluid and each additive
pumped, including
(A) a description of each
hydraulic fracturing fluid pumped, identified by individual base fluid or
additive; the description must include
(i)
the trade name for the base fluid or additive;
(ii) the supplier of the base fluid or
additive; and
(iii) a brief
description of the purpose of the base fluid or additive; that purpose may be
expressed as acid, biocide, breaker, brine, corrosion inhibitor, crosslinker,
de-emulsifier, friction reducer, gel, iron control, oxygen scavenger, pH
adjusting agent, proppant, scale inhibitor, surfactant, or another similar
brief description; and
(B) the chemical ingredient name of, and the Chemical Abstracts
Service (CAS) registry number assigned to, each base fluid and additive used;
the actual or maximum concentration of each chemical ingredient in each base
fluid and additive used must be provided in percent by mass; the actual or
maximum concentration of each chemical ingredient in the hydraulic fracturing
fluid must be provided in percent by mass: freeze-protect fluids pumped before
or after hydraulic fracturing may not be
included.
(i)
Before submitting a Report of Sundry Well Operations under (h) of this section,
the operator shall
(1) post information
required by the Interstate Oil and Gas Compact Commission and the Ground Water
Protection Council on the FracFocus Chemical Disclosure Registry, or its
successor database, maintained on the Internet by those organizations;
and
(2) file a printed copy and
electronic copy of that information, in a format acceptable to the commission
and as an attachment with the Report of Sundry Well
Operations.
(j) The
commission may require water sampling of water wells after hydraulic
fracturing. If required, and in accordance with a sampling and monitoring plan
approved by the commission, water sampling may consist of collection of water
data within a one-half mile radius of the wellbore trajectory after hydraulic
fracturing. The operator shall detail the well selection process for
identifying wells to sample. Methods, parameters, and analysis must be similar
to those under (a)(4) of this section as required by the commission.
(k) Any information required to be filed
under this section that the filing party believes to be a confidential trade
secret shall be separately filed in an envelope clearly marked "confidential"
along with a list of the documents that the party believes to be wholly or
partially nondisclosable as trade secrets, and the specific legal authority and
specific facts supporting nondisclosure. The commission will review the
information, and will maintain it as confidential. If the commission receives a
request under
AS
40.25.100-40.25.295 (Alaska Public Records
Act) for disclosure of the information, the commission will promptly forward
the request to the party claiming confidentiality. Not later than five business
days after receiving the request, the party claiming confidentiality shall file
with the commission an affidavit verifying that the documents remain wholly or
partially confidential, identifying any portions of the document that are not
confidential, and setting out the specific facts and legal authority supporting
nondisclosure. After reviewing the affidavit, in accordance with and within the
time allowed to respond under
2
AAC 96.325, the commission will determine whether to
provide the party making the public records request the requested documents or
the list of nondisclosable documents, the specific legal authority and facts
supporting nondisclosure, and the affidavit provided by the party claiming
confidentiality. The commission will notify the party claiming confidentiality
if an appeal is requested under
AS
40.25.123(e) and
2
AAC 96.340, or if judicial relief is sought under
AS
40.25.124 or
40.25.125.
(l) Upon written request of the operator, the
commission may modify a deadline in this section upon a showing of good cause,
approve a variance from any other requirement of this section if the variance
provides at least an equally effective means of complying with the requirement,
or approve a waiver of a requirement of this section if the waiver will not
promote waste, is based on sound engineering and geoscience principles, will
not jeopardize the ultimate recovery of hydrocarbons, will not jeopardize
correlative rights, and will not result in an increased risk to health, safety,
or the environment, including freshwater.
(m) In this section,
(1)
"additive" means a chemical substance or combination of substances, including a
proppant, that is contained in a hydraulic fracturing fluid and that is
intentionally added to a base fluid for a specific purpose, whether or not that
purpose is to create fractures in a formation;
(2) "chemical ingredient" means a discrete
chemical constituent that is contained in an additive and that has its own
Chemical Abstracts Service (CAS) registry number or other specific name or
identity;
(3) "diesel range
organics" means mid-range petroleum products, including diesel fuel, with
petroleum hydrocarbon compounds corresponding to an alkane range from the
beginning of n-decane (C10) to the beginning of n-pentacosane (C25) and with a
boiling point range between approximately 170 - 400 degrees
Centigrade;
(4) "fracturing
string" means any pipe or casing string used for the transport of hydraulic
fracturing fluids during hydraulic fracturing operations;
(5) "gasoline range organics" means light
range petroleum products, including gasoline, with petroleum hydrocarbon
compounds corresponding to an alkane range from the beginning of n-hexane (C6)
to the beginning of n-decane (C10) and with a boiling point range between
approximately 60 - 170 degrees Centigrade;
(6) "hydraulic fracturing" means the treatment of a well by the
application of hydraulic fracturing fluid under pressure for the express
purpose of initiating or propagating fractures in a target geologic formation
to enhance production of oil or natural gas;
(7) "hydraulic fracturing fluid" means the fluid, including the
applicable base fluid and all additives, used to perform a particular.hydraulic
fracturing treatment;
(8)
"hydraulic fracturing treatment" means all stages of the treatment of a well by
the application of hydraulic fracturing;
(9) "proppant" means treated sand, a
manufactured ceramic material, or another solid material designed to keep a
hydraulic fracture open during or after hydraulic fracturing
treatment;
(10) "stage" means any
separate interval treatment that initiates a new fracture within the
wellbore;
(11) "water well" means
a well producing freshwater that serves as a source of drinking water for human
consumption or agricultural purposes.
Access to the FracFocus Chemical Disclosure Registry is
available at www.fracfocus.org.
Authority:AS
31.05.030
