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killing through bop line well control assy

Deep water hydrostatic head control - SYKORA; JAMES H.

What I claim is: 1. In a marine riser and BOP stack assely positioned near the bottom of a water body and having multiple rams, a kill line and a choke line, the improvement to which comprises connecting an eductor to said choke line to receive any kick gas from said assely through an eductor intake opening wherein said eductor comprises a suction end openable to …

Blowout Preventers BOP Stack Components & Types - Drilling

23/12/2017· Choke & Kill Lines. Each choke and kill line BOP outlet shall be equipped with two full bore valves, the outer valve of which will be hydraulically operated (preferably fail-safe closed). The minimum diameter of the choke line will be 3″ ID, while the kill line should have not less than a 2″ ID. Articulated choke lines (Chiksan) are not

Choke and kill line systems for blowout preventers

19/2/2013· +Upgraded to kill/bullhead wells through the killing hose. It does not allow for circulation. Disadvantage-Heavier equipment. It has to be guided and supported on a separate lift line to maintain stability as the lubrior is deployed and operated on the seafloor.-Not viable to be used on deepwater or depths > 500 mTVD.-All fully direct hydraulic control systems plus, …

DrillingForGas - Well Control - Balanced Mud Method

It is possible to avoid the necessity to take the choke line pressure drop into account during well killing operations by using the kill line as a pressure conduit to monitor Pa at the subsea BOP stack (kill line fail safe valves open and the kill line valve upstream of the choke closed).

2P37492, Choke Valve Source - Weir Group

Most SPM® products generate, control or direct pressurized fluids; including choke and kill lines and well service lines for cementing, fracturing, acidizing, and testing. General Description of Choke Valve Operation: The SPM® Choke Valve restricts the flow through the valve by reducing the flow area through the valve body to achieve a desired flow rate. 2” Choke Valves have a …

Study on Well Control Technology of High Temperature

1/1/2014· Keywords: Geothermal drilling, Well control, RBOP, Balanced Drilling In the geothermal wells drilling process, the annulus hydrostatic column is usually higher than the pore pressure, two situations that can cause geothermal well blowout: circulating hot fluids from deeper depths to the surface, resulting in the fluids flashing to steam, which causes a loss in hydrostatic …


Most kill procedures can be placed in two egories: (1) those for killing through tubing with and without holes, and (2) for killing through the annulus. Concepts and procedures for killing an abnormally pressured, producing well are essentially the same as those for normally pressured wells. The primary difference is the use of high density kill fluids in place of 9.0 ppg brine water …

Choke Line - an overview | ScienceDirect Topics

Howard Crumpton, in Well Control for Completions and Interventions, 2018. 14.1.5 Choke line friction. When circulation returns are taken through the choke, a significant pressure loss is seen. This is caused by friction losses in the small diameter choke line between the subsea BOP and the rig floor. This pressure drop is observed during slow circulating rate measurements when …

Oil well control - Wikipedia

Oil well control is the management of the dangerous effects caused by the unexpected release of formation fluid, such as natural gas and/or crude oil, upon surface equipment of oil or gas drilling rigs and escaping into the atmosphere. Technically, oil well control involves preventing the formation gas or fluid (hydrocarbons), usually referred to as kick, from entering into the …

API Specifiion 16C

API Specifiion 16C Choke and Kill Equipment SECOND EDITION | MARCH 2015 | 114 PAGES | $150.00 | PRODUCT NO. G16C02 This specifiion establishes the minimum requirements

Name: Person(s) Completing Name

The complete assely of well control equipment, including preventers, spools, valves, and nipples connected to the top of the wellhead or wellhead asselies. buffer tank A targeted, horizontal, cylindrical tank that changes the direction of fluid flow downstream of the choke and serves to direct flow to the flare line or gas buster.

Figure Figure - Well Control - Rig Worker

6/1/2021· The type ''HCR'' pressure operated gate valves is a flow line valve requiring relatively low operating pressures. This is a single ram, hydraulic gate valve packed with elements similar to the old ''QRC'' ram assely. The closing ratio of well pressure to hydraulic operating pressure is approximately 8 to 1. Available sizes are 4-inch 3000 to 5000 psi working pressure, and 6-inch …

Academy Case Study: The Deepwater Horizon Accident Lessons

24/5/2010· (The kill line is one of three pipes, each approximately 3 inches in diameter, that run from the rig to the BOP to allow the crew to circulate fluids into and out of the well at the sea floor.) The pressure on the kill line during the negative- pressure test should have been identical to the pressure on the drill pipe, as both flow paths went to the same place (and both should …

Procedures for Inspection, Maintenance, Repair, and

ADDENDUM 1 TO PROCEDURES FOR INSPECTION, MAINTENANCE, REPAIR, AND REMANUFACTURE OF DRILLING EQUIPMENT 3 C.3.7 The user shall also ensure that procedures for utilizing features designed to control the top of the BOP stack are imple- mented until either the moonpool guidance system described in C.3.6 (if provided) is engaged, and / or the BOP …

API Std 53 - Blowout Prevention Equipment Systems for

12/8/2015· 6.2 53-07-15 Can you please advise if a by-pass line is require on surface choke and kill manifolds. No, the bleed line (line that by-passes the chokes) is optional. 53 4th Edition, Nov. 2012 53-02-16 Minimum nominal inside diameter (ID) for lines downstream of the chokes shall be equal to or greater than the nominal connection size of the choke inlet and outlet. …

BOP Well Control Hose - PME Industrial

BOP control hoses feature in high pressure resistance, high temperature resistance and fire resistance. Specified standard API 16D, blowout preventer hoses are ideally suited for high pressure hydraulic appliions for drilling well control equipments, and capable of containing the hose rated working pressure in a flame temperature of 1300°F (700°C) for a 5-minute period.


All high-pressure connections associated with the well control equipment (i.e. choke & kill line valves, choke manifold valves, TIW valves, floor safety valves, inside BOP (Gray) valves) are to be isolated and pressure tested during each BOP test. When the integrity of the BOP stack has been compromised (i.e. changing rams or lifting the stack), the compromised component must be re …

Subsea blowout preventer (BOP): Design, reliability

these fluids try to force their way through the annulus. Primary well control during drilling is achieved through a counterbalance of reservoir pressure by hydrostatic mud pressure. The appropriate safety margin is achieved by varying the fluid density. When this pressure is lost during a kick, the Blowout Preventer (BOP) is employed as an alternative. As a large …

Back-Pressure Valve installed in tubing hangers

28/11/2018· If during the life of the well it becomes necessary to remove the Christmas tree or repair the lower master valve, the back pressure valve can be reinstalled in the hanger without killing the well. The lubrior consists of a rod, which works through a yoke provided with two stuffing boxes. By closing the vent valve and opening the equalizing valve, well pressure acts …

Blowout preventer - Wikipedia

A blowout preventer (BOP) (pronounced B-O-P, not "bop") is a specialized valve or similar mechanical device, used to seal, control and monitor oil and gas wells to prevent blowouts, the uncontrolled release of crude oil or natural gas from a well.They are usually installed in stacks of other valves. Blowout preventers were developed to cope with extreme erratic pressures and …

Subsea test tree functionality in the drilling and

1/3/2019· The purpose of the subsea test tree (SSTT) is to provide well barriers within the high pressure upper completion string, and to facilitate well control in the event of an emergency disconnection of the rig from the well, without requiring the blowout preventer (BOP) to shear the shear joint. The lower ball valve should be capable simultaneous

An introduction to well intervention

Primary Well control Stuffing Box (Slickline) Grease Head (Braided/Electric line) Secondary Well control BOP c/w Dual blind rams Slickline BOP c/w inverted dual blind rams Braided/Electric line Grease injection between rams Tertiary Well control BOP c/w Shear Ram In the event tree MV cannot shear wire

Well control stack for CT operations - PetroWiki

26/6/2015· Assely of well-control stack. Typically, a kill-line flange inlet is positioned directly below the tubing shear ram set and above the slip ram set in the well-control stack. Two valves rated to the maximum allowable working pressure (MAWP) of the well-control stack are mounted onto the kill-line flange, which typically includes a high-pressure check valve installed in the …

Choke Manifold And Remote Choke Panel Drilling Fluid

22/6/2017· Choke Manifold. This set up is designed to full sized model of a typical choke manifold on the rig. It consists of eleven gate valves operated by several turns of valve handle, Remote Choke (activated from a panel), Remote Outer Choke Valve and Kill Line valve (both controlled from the BOP Panel) as well as the Left and Right Manual Chokes. Both drill pipe …

E-Z Valve product sheet - Schluerger

in the BOP stack of a jackup or land rig during well testing. The pipe rams close around a slick joint above the valve, protecting the annulus, while the tool’s ball closes to secure the well at BOP level. The tool’s pump-through design allows killing the well while in the fail-safe closed position and while a differential pressure The E-Z Valve tool is normally closed by a spring and


7.1 classifiion of surface bop well control equipment..126 7.2 choke manifold and kill line manifold..141 7.3 control system requirements for surface bop stacks..152 7.4 tests for

Pressure Control Equipment | BOP / Blowout Preventers

A Ram BOP is a safety unit used during the drilling or workover operation to control well bore fluid pressure. The BOP achieves wellbore pressure control by closing rams to seal around drilling tubulars and open hole, or to shear and seal drilling tubulars under various drilling conditions. Under normal drilling the BOP experiences little or no internal pressure. However, if while …

Wellhead Products

Control Line inlet preparation and integral manual or actuated Lower Master Valve. Features and Benefits • Available in studded or flange bottom sizes from 7-1/16” to 11” and studded or flange top sizes from 2-1/16” to 4-1/16”, with pressure ratings for both to 20,000 psi • PSL-1 to 3G certified • PR-1 certified

4th - SlideShare

16/3/2012· BOP PRESSURE TEST 1. Run-in 2-3 stands of HWDP 2. Make-up Test Plug 3. Make-up 1 single of 5” D/P 4. Make-up Kelly 5. Open McEvoy valve and keep it in open position 6. Make-up 2” hole fill-up line 7. Close Annular or Ram BOP (whichever is tested) 8. Flushed all the lines (through choke manifold) 9.