otherwise provided for by the permit to drill issued under ARM 36.22.601 and
ARM 36.22.602, or by board order issued after public notice and hearing, the
owner must provide blowout preventers and well control equipment on all wells in
accordance with the following rules.
(a) For wells in areas of abnormal or unknown
formation pressures, proper blowout preventers must consist of hydraulically-operated
single or double ram-type preventers with at least one pipe ram and one
blind ram, and an annular-type preventer. Additional equipment must
include upper and lower kelly cocks; mud pit level indicators with alarms
and/or flow sensors and alarms; and choke manifolds, kill lines, and other well
control equipment sufficient to handle all pressure kicks. Accumulators must
maintain a pressure capacity reserve at all times to provide for the operation
of the hydraulic preventers and valves with no outside source of pressure.
(b) For development wells and in all areas of known
formation pressures, blowout prevention and well control equipment must be
(c) The owner must maintain all blowout prevention
and well control equipment in good working order.
(2) Drilling spools for blowout preventer stacks
must meet the following minimum specifications:
(a) for working pressures rated at 3,000 or 5,000
pounds per square inch (psi) , flanged, studded, or clamped side outlets of no
less than 2 inches nominal diameter.
(b) for working pressures rated at 10,000 and 15,000
psi, one 2-inch side outlet and one 3-inch side outlet.
(3) The rated working pressure of all blowout
preventers and well control equipment must equal or exceed the maximum
anticipated pressure to be contained at the surface.
(4) Wellhead outlets must not be used for choke or
kill lines in areas of abnormal or unknown formation pressures. Such outlets
may be employed for auxiliary or back-up connections to be used only if
the primary control system fails.
(5) The owner or operator must test blowout
prevention and well control equipment according to the following standards.
(a) Ram-type blowout preventers and well
control equipment, including casing, must receive initial pressure testing to
the least of the manufacturer's fullworking pressure rating of the equipment,
50 percent of the minimum internal yield pressure of any casing subject to
test, or one psi per foot of the last casing string depth. Annular-type
blowout preventers must receive initial pressure testing in conformance with
for any reason, a pressure seal is disassembled, the owner or operator must
test the full working pressure of that seal before resuming drilling
operations. However, if the affected seal is an integral part of the blowout
preventer stack, the owner or operator may obtain permission from a board
representative to proceed without testing the seal.
addition to the initial pressure tests, the owner or operator must check ram-
and annular-type preventers for physical operation each trip but not more
than once each twenty-four (24) hour period.
blowout preventer components, with the exception of annular preventers, must be
tested monthly to the least of 50 percent of the manufacturer's rated pressure,
the maximum anticipated pressure to be contained at the surface, one psi per
foot of the last casing string depth, or 70 percent of the minimum internal
yield pressure of any casing subject to test.
owner or operator must note all tests of blowout preventer and well control
equipment on the driller's log, which must be made available to the board upon
request. The board may require the operator or the drilling contractor to
provide a signed and sworn affidavit attesting to the sufficiency of the
blowout prevention equipment and any testing of such equipment.
owner or operator must submit a schematic diagram of the proposed blowout
prevention and well control equipment with the application for permit to drill.
areas where hydrogen sulfide or sour gas may be encountered, the following
additional equipment and precautions are required:
(a) a blowout preventer
closing unit located in a safe place easily accessible to rig personnel.
remote auxiliary choke control panel to operate the choke manifold set up at a
safe distance upwind from the rig floor.
(c) a remote kill line
sufficient to permit use of an auxiliary high-pressure pump.
placement of the drilling fluid inlet line to the degasser close to the
drilling fluid discharge line from the mud/gas separator.
(e) provisions to flare toxic gases with an adequate degasser, discharge lines,
check valves, a vertical flare stack, and a gas ignition system.
(f) provisions for personnel training; personnel protective equipment including
sensors, alarms, and breathing equipment; warning signs; and wind direction flags to safeguard against injury or