Open Hole: Inflate Straddle
The Full Bore Rotating Control Head is a compact high pressure, Surface Test Tree with an integrated swivel. With 4 valves, the rotating control head provides a primary flow control barrier via the master valve and secondary barriers from the kill, flow and swab valves. The integral swivel allows the drill string to rotate freely from above (top drive) or below (rotary table) while the kill and flow lines remain stationary.
The Pump Out Sub is used to circulate fluid from the drill string after the drill stem test has been completed, and the drill string is ready to be removed.
The Pump Out Sub is used to circulate fluid from the drill string after the drill stem test has been completed, and the drill string is ready to be removed.
The Gauge Carrier holds up to four or eight electronic memory pressure and temperature gauges depending on the model.
The Hydraulic Valve is a down-hole valve used in opening and closing the flow from the test zone. The tool gives positive surface indications of opening: a sudden, small movement of the drill pipe, combined with a slight reduction in drill pipe weight.
The Sampler catches a sample of produced fluid and retains the sample at the down hole pressure of the interval at the instant that the hydraulic valve is closed. The valves of the Sampler are opened and closed by the movement of a mandrel extending from the hydraulic valve.
The Squeeze Tool is a check valve that opens to balance tubing to annular pressure when the tubing pressure exceeds annular pressure. This prevents supercharging of the formation in the interval while setting packers or opening the down hole hydraulic valve.
The Gauge Carrier holds up to four or eight electronic memory pressure and temperature gauges depending on the model.
The Extension Joint is used to allow free travel of the work-string. This allows operators to get a good indication of hole drag in deviated holes. The Extension Joint also allows free pipe movement before the Hydraulic Valve is operated.
The Hydraulic Jar is used in the event that equipment becomes stuck in the well bore and provides an upward shock to assist in freeing the tools. Over-pull at surface is applied to the string, which causes oil to move through a flow restrictor.
The Tension Safety Joint is a two-stage emergency disconnect tool that can be used to mechanically separate the drill string in a controlled way. If the string is stuck at a packer or elsewhere, it can be operated to recover tools above the Safety Joint. The lower half of the safety joint that is left down hole provides a connection for fishing tools.
The Inflate Pump is a down hole piston pump which delivers drilling fluid from the well bore to the inflate packers. The Inflate Pump is activated by rotating the drilling string at approximately 60 R.P.M.
The Suction Screen filters the larger particles from the drilling mud before it can enter the Inflate Pump. Located directly below the Inflate Pump, drilling mud is drawn in through the screen up to the Inflate Pump and back down through a flow passage to the Packer Elements.
The Inflate Release System enables multiple inflate tests without having to come out of the hole after each test. The Release System consists of a hydraulic piston/cylinder arrangement that acts as a valve to facilitate mud flow movement in two directions:
· Inflation = Inflate Pump to packers
· Deflation = Packers to well annulus
The Upper Packer Assembly is designed to serve four functions.
1. Mounting of the rubber packer element.
2. Delivery or removal of drilling mud to the packer elements during the test inflation and
deflation process.
3. Inflation of packer elements to seal the top of the test interval.
4. Equalization of hydrostatic pressure above and below the test interval.
The Gauge Carrier holds up to four or eight electronic memory pressure and temperature gauges, depending on the model.
The Lower Packer Assembly is designed to serve four functions.
1. Mounting of the rubber packer element.
2. Delivery or removal of drilling mud to the packer elements during the test inflation
and deflation process.
3. Inflation of packer elements to seal the top of the test interval.
4. Equalization of hydrostatic pressure above and below the test interval.
The Drag Spring is designed to resist turning in the hole when the drill string is rotated. This resistance transmits torque to power the Inflate Pump.
The Inflatable Packer System isolates an open hole interval. It can be configured with one (Bottom Hole) or two packers (Straddle). The Inflate Straddle configuration is capable of multiple resets allowing independent testing or treatment of multiple intervals with one trip in the hole. Right hand rotation of the drill pipe or tubing at 20 – 60 rpm for 30 to 45minutes drives the Inflate Pump, which draws filtered annular fluid (drilling or completion fluid) through the Suction Screen and inflates the packers. Upward pull opens the Inflate Release deflating the Upper and Lower Packers. The process can be repeated for multiple intervals.
Northstar’s Inflatable Packer System is equipped with an integrated Bypass passage equalizes pressure above and below the interval to maintain well control (overbalance) and prevent skidding during testing and prevent swabbing while tripping in/out of hole.
Benefits
- Resets - Multiple tests with one trip
- Lower Isolation – Isolate and independently prove reservoirs
- Can test far off bottom after the well total depth is achieved (TD)
- Seals in large wellbore washouts
- Continuous rotation prevents differential sticking - Best for deviated open hole
Deliverables
- Formation Pressure (P*) and temperature charts for Pressure Transient Analysis (PTA)
- PTA Deliverables: Permeability (k), damage/skin, Deliverability, Flow Regime, Reservoir Boundaries
- Production Rate - Gas and liquid
- Downhole reservoir fluid samples
Specifications
- Packer pressure differential: 5,000 PSI
- Absolute pressure: 8,000 PSI
- Temperature: 140 C / 284 F
- Hole sizes: 6.125” to 12.25”
- Wash-out: 30%
- Deviation: up to 90°
- Interval size: 1.58 to 40 meters
The Full Bore Rotating Control Head is a compact high pressure, Surface Test Tree with an integrated swivel. With 4 valves, the rotating control head provides a primary flow control barrier via the master valve and secondary barriers from the kill, flow and swab valves. The integral swivel allows the drill string to rotate freely from above (top drive) or below (rotary table) while the kill and flow lines remain stationary.
The Pump Out Sub is used to circulate fluid from the drill string after the drill stem test has been completed, and the drill string is ready to be removed.
The Pump Out Sub is used to circulate fluid from the drill string after the drill stem test has been completed, and the drill string is ready to be removed.
The Gauge Carrier holds up to four or eight electronic memory pressure and temperature gauges depending on the model.
The Hydraulic Valve is a down-hole valve used in opening and closing the flow from the test zone. The tool gives positive surface indications of opening: a sudden, small movement of the drill pipe, combined with a slight reduction in drill pipe weight.
The Sampler catches a sample of produced fluid and retains the sample at the down hole pressure of the interval at the instant that the hydraulic valve is closed. The valves of the Sampler are opened and closed by the movement of a mandrel extending from the hydraulic valve.
The Squeeze Tool is a check valve that opens to balance tubing to annular pressure when the tubing pressure exceeds annular pressure. This prevents supercharging of the formation in the interval while setting packers or opening the down hole hydraulic valve.
The Gauge Carrier holds up to four or eight electronic memory pressure and temperature gauges depending on the model.
The Extension Joint is used to allow free travel of the work-string. This allows operators to get a good indication of hole drag in deviated holes. The Extension Joint also allows free pipe movement before the Hydraulic Valve is operated.
The Hydraulic Jar is used in the event that equipment becomes stuck in the well bore and provides an upward shock to assist in freeing the tools. Over-pull at surface is applied to the string, which causes oil to move through a flow restrictor.
The Tension Safety Joint is a two-stage emergency disconnect tool that can be used to mechanically separate the drill string in a controlled way. If the string is stuck at a packer or elsewhere, it can be operated to recover tools above the Safety Joint. The lower half of the safety joint that is left down hole provides a connection for fishing tools.
The Inflate Pump is a down hole piston pump which delivers drilling fluid from the well bore to the inflate packers. The Inflate Pump is activated by rotating the drilling string at approximately 60 R.P.M.
The Suction Screen filters the larger particles from the drilling mud before it can enter the Inflate Pump. Located directly below the Inflate Pump, drilling mud is drawn in through the screen up to the Inflate Pump and back down through a flow passage to the Packer Elements.
The Inflate Release System enables multiple inflate tests without having to come out of the hole after each test. The Release System consists of a hydraulic piston/cylinder arrangement that acts as a valve to facilitate mud flow movement in two directions:
· Inflation = Inflate Pump to packers
· Deflation = Packers to well annulus
The Upper Packer Assembly is designed to serve four functions.
1. Mounting of the rubber packer element.
2. Delivery or removal of drilling mud to the packer elements during the test inflation and
deflation process.
3. Inflation of packer elements to seal the top of the test interval.
4. Equalization of hydrostatic pressure above and below the test interval.
The Gauge Carrier holds up to four or eight electronic memory pressure and temperature gauges, depending on the model.
The Lower Packer Assembly is designed to serve four functions.
1. Mounting of the rubber packer element.
2. Delivery or removal of drilling mud to the packer elements during the test inflation
and deflation process.
3. Inflation of packer elements to seal the top of the test interval.
4. Equalization of hydrostatic pressure above and below the test interval.
The Drag Spring is designed to resist turning in the hole when the drill string is rotated. This resistance transmits torque to power the Inflate Pump.
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