Completion Accessories

Enhance recovery with customized tubing-mounted and flow control equipment.
they are:-
1-Chemical Injection Mandrels
2-Expansion and Separation Assemblies3-Expansion Joints
4-On-Off Attachments
5-Safety Joints
6-Locks and NipplesAccessories
7-Blanking Plugs and Standing Valves
8-Sliding Sleeves and Tubing Drains Accessories
9-Smart Sub Assemblies
10-Tubular Components

ntelligent Completions

Well completions connect you to your reservoir and help you lower production costs, lengthen reservoir life, and optimize hydrocarbon recovery with completions designed for the life of your oil or gas well.
Intelligent completions obtain downhole pressure and temperature data in real time to identify problems in the reservoir or wellbore and optimize production without costly well intervention. Sensing, data transmission, and remote control of zonal flow to isolate the formation from completion fluids help operators minimize fluid loss, manage the reservoir, maintain well integrity, and maximize production.

Flow Control

Flow control valves are used in multizone intelligent completion, comingled-flow completions, auto (natural) gas-lift wells, and well environments with scale deposition, severe erosion, or high temperature conditions.
Flow control valves modify the flow behavior as required for specific operations and can be operated automatically, manually, or remotely as part of an intelligent completion. Used to control upper and lower producing zones, they reduce the production of unwanted water and gas, minimize the costs and risks of well interventions, and maximize well productivity.

Permanent Monitoring Systems

WellWatcher permanent monitoring systems

WellWatcher permanent monitoring systems integrate the most advanced permanent downhole gauges with surface data communication to allow remote monitoring of wells and reservoirs in real time. Pressure, temperature, and flow rate data are transmitted to remote location via satellite, Internet, or cable.

WellWatcher Flux System

The system obtains reservoir data across the sandface of subsea wells in real time to monitor and characterize flow profiles. Electromagnetic induction enables wireless communication and power transmissions between the upper and lower completions.

WellWatcher DTS Fiber Optics

The system captures and transmits distributed temperature profiles with fiber optics reliably, accurately, and in real time to identify the time, location, and reason for changes in flow. Data are transmitted to the surface and then to remote locations via satellite, Internet or cable.

Pressure and Temperature Gauges

These gauges obtain highly accurate, stable measurements with gauges ranging from simple systems to downhole networks.

WellNet Downhole Network and Communication Systems

This telemetry system provides bidirectional, high-rate data communication and transfers electrical power to downhole tools.

Conveyance Components

Connectors and cables are rigorously tested and qualified to meet the highest standards for reliability.

Zonal Isolation

QUANTUM Multiport Packer

The QUANTUM multiPort (QMP) packer is a hydraulically set retrievable packer particularly suited for bypass applications. It is used as the upper packer in stacked configurations in completions with surface-controlled subsurface flow-control valves and tubingmounted reservoir monitoring equipment.

This packer is designed to allow onsite feed-through and connection of electric and hydraulic conduits. Testing of control-line fittings on the packer is accomplished after feed-through. This feature greatly simplifies rig operations and reduces control line terminations. The packer features a one-piece mandrel design with an eccentric flow bore. Bypass lines are fixed relative to the mandrel, eliminating relative movement during releasing. This design facilitates release regardless of the prevailing tubing load condition, i.e., tension or compression at the packer. The QMP packer allows simultaneous setting of multiple packers and is capable of simultaneous testing of bypass seals on the rig floor.

The hydraulically set QMP packer features twin setting pistons that fully energize the sealing elements prior to anchoring the slips.

Retrieval of the QMP packer is accomplished by means of a through-tubing intervention tool and subsequent upward pull on the tubing.

QMP packers are available for a variety of service applications, including H₂S and CO₂ environments.

The QMP packer is designed and tested in accordance with ISO 14310 grade V3.

Benefits

• Simplified operations reduce rig costs.
• Enhanced capabilities allow onsite product customization.
• Reduced rig time achieved by simultaneous setting of multiple packers.

Project Management

Intelligent completions present a wide range of complex technical challenges, especially in deepwater. The Schlumberger Project Management group works closely with operators to plan and design projects; manufacture, test, and install equipment; ensure equipment reliability; and troubleshoot complications. Close collaboration with the operator is considered critical to the success of each project.

Casing

Casing

The delivery system consists of two sizes of casing which were developed to fit two ranges of borehole sizes.

MP38 System has an inside diameter of roughly 38mm (1.5in) and is generally used in boreholes or casing whose inside diameter ranges from 76mm (3in) to 115mm (4.5in).
MP55 System has an inside diameter (ID) of 55mm (2.25in) and is generally used in boreholes or casing whose ID ranges from 98mm (3.9in) to 170mm (6.25in).

Both systems are designed for operation at maximum depths that range from 300m (1,000ft) to over 1,500m (5,000ft).

Both systems are available in plastic and in stainless steel. Steel systems are used in situations where tensile strengths, hydraulic pressures or temperatures are higher than would be suitable for the plastic systems

Regular Couplings

Couplings joining the casing together consist of regular couplings and port couplings. Regular couplings simply join two pieces of casing together, while port couplings provide a controllable pathway for formation fluids on the outside of the coupling to reach the inside of the coupling.

Measurement Ports

The measurement port is the heart of the MP System. Measurement ports are used for the majority of the pressure measurement and fluid sampling operations. Each measurement port coupling has a small check valve that contains a spring that keeps the valve closed so that it will not open due to the application of an exterior fluid pressure. The measurement port is operated by means of a MOSDAX* probe that is lowered into the borehole, locates the measurement port and opens the port valve.

Pumping Ports

In contrast to the measurement port, a pumping port coupling has several relatively large openings. The total area of these openings is approximately equal to the cross-sectional area of the inside of the casing. A sliding sleeve valve controls the pumping port openings. Either mechanical or hydraulic operating tools operate pumping port valves.

Packers

Different levels (monitoring zones) in a borehole are separated by placing impervious layers of backfill around the outside of the casing between monitoring zones or by using water inflated packers.

Westbay has developed a series of modular hydraulically inflated packers that are mounted on plastic or stainless steel mandrels. Each packer has an individual inflation valve attached to the packer. After the packers have been positioned in the borehole, a packer inflation tool is lowered into the borehole and packers are inflated individually.

Magnetic Collars

Magnetic collars can be attached to the outside of the casing near components that will be visited frequently. The collars contain ceramic magnets. When a probe passes by a magnetic collar, a reed switch in the probe is triggered and a "beeping" noise is heard at the surface. This assists the probe operator in determining the location of the probe in the borehole.

Specialized Components

A number of special components are available. These include:

• Y-connectors that permit twin–tubes to be installed in the upper part of the drillhole. This arrangement permits pumping to occur in one tube while sampling and pressure monitoring occur in the other.
• Telescopic casings that can extend or be compressed after installation. These protect the casing components should there be a tendency for the borehole to lengthen or shorten in the future.
• A borehole completion kit that permits de-stressing of the plastic casing during installations in deep boreholes.
  

Tools for Casing Installation and Recovery

Packer Inflation Tools: Each casing system (MP38 and MP55) has a specific tool to inflate packers. These tools have associated winches, hoses and control units for handling the packer inflation activities.

Pumping Port Operating Tools: The operation of pumping ports requires tools that will open and close the pumping port valve. A separate mechanical "open/close" tool is available for the plastic MP38 System. Hydraulic pumping ports for the steel MP38 System and the MP55 System are operated by a modified MOSDAX sampling probe or by a special tool.

Casing Recovery Tools: Casing recovery tools are available for those projects where it is necessary to demonstrate recovery capability before installation proceeds

Schlumberger drilling cd's

Schlumberger drilling cd's

Password to decompress

www.geo2all.com

With highly interactive show with visual and vocal effects illustrating drilling &other topics related to oil production.

the cd's are explained in 6 languages:

:: Arabic

:: English

:: French

:: Spanish

:: Indonesian

:: Portuguese

contents


cd1 : An introduction to drilling rigs and main components of drill string

part1

part2

Cd2:BOP Equipments

part1
part2

Cd3:Drilling Fluids and Mud Test

part1
part2

Cd4:Mud circulation and treating Equipments

part1
part2

Cd5:Hoisting Equipments

part1
part2
part3

Cd6:Rotating Equipments & Mast and Substructure

part1
part2

Cd7:Pipe Handling

part1
part2

Cd8:Casing and Cementing

part1

Cd9:Well logging, Mud logging and Drill stem test

part1

Cd10:Power System and instrument

part1
part2

Password to decompress

www.geo2all.com

Damage during drilling

1-Tubing Damage
2-Matrix Damage
3-Deposition within Porous Formation
Reason for Scale Control: Tubing Damage
•Tubing ID Restriction
1-Constrained production
2-Often layered with scale, wax, asphaltene, etc.
•Completion components blocked with scale
1-Gas Lift Mandrels
2-SSSV
3-Nipples, ..etc
•Corrosion under scale deposition
1-Bacterial / H2S
2-Pitting
3-Loss of steel integrity
Reason for Scale Control: Matrix Damage
1-Hydrocarbon flow through water-saturated matrix
2-Scale deposition restricts flow
3-Scale reduces matrix permeability
4-Complete scaling of pore throat not likely; however,
5-Small quantity of scale =large loss in permeability
6-Large loss in permeability =significant reduction in productivity
Organic Deposit
A type of damage in which heavy hydrocarbons precipitate when temperature or pressure is reduced.
1-These deposits are commonly located in the tubing,gravel pack and perforations, or inside the formation . The injection of cold treating fluids promotes the formation of organic deposits.
2-Organic deposits such as paraffins or asphaltenes are resolubilized using aromatic organic solvents such as toluene or xylene.
3-Small amounts of alcohol help to further dissolve asphaltenes.
Organic deposits are heavy hydrocarbons (paraffins or asphaltenes) that precipitate as the pressure or temperature is reduced.
They are typically located in the tubing, perforations or formation.
1. Paraffins: (dissolved in oil)
Paraffins are the simplest of hydrocarbons. They are composed of only carbon and hydrogen atoms, and the carbons occur as an unbranded chain.
2. Asphaltenes: (undissolved, but suspended as a colloid in oil)
Asphaltenes are organic materials consisting of condensed aromatic and naphthenic ring compounds with molecular weights of several hundred to several thousand. In “solution,” they usually exist as a colloidal suspension,
3. Tar:
-Tar is simply an asphaltene or other heavy-oil deposit. It cannot be removed by acid or mutual solvents. Removal requires dispersion in an aromatic solvent, and energy is typically necessary to achieve removal.
4. Resins :
-(Peptizing agent, dissolved in oil, help suspend asphaltene in oil)
5. Wax:
-A combined deposit of paraffins, asphaltenes, resins, mixed with clays, sand, and debris (dissolved in oil)

Scale Inhibitor

A chemical treatment used to control or prevent scale deposition in the production conduit or completion system.
Scale-inhibit or chemicals may be continuously injected through a down hole injection point in the completion, or periodic squeeze treatments may be undertaken to place the inhibitor in the reservoir matrix for subsequent commingling with produced fluids.Some scale-inhibitor systems integrate scale inhibitors and fracture treatments into one step, which guarantees that the entire well is treated with scale inhibitor. In this type of treatment, a high-efficiency scale inhibitor is pumped into the matrix surrounding the fracture face during leak off.
It adsorbs to the matrix during pumping until the fracture begins to produce water. As water passes through the inhibitor-adsorbed zone, it dissolves sufficient inhibitor to prevent scale deposition. The inhibitor is better placed than in a convention a scale-inhibitor squeeze, which reduces the re-treatment cost and improves production.

Inhibitor Types

There are a number of scale inhibitor types:
1.Inorganic phosphates.
2.Organo phosphorous compounds.
3.Polyvinyl sulphonate co-polymers.
4.Organic polymers.
5.Blends of phosphonates and polymers.

Scale inhibitors prevent undesirable buildup on your equipment. Appropriate treatment by NCP Scale Inhibitors will extend the life of industrial equipment and provide optimal process conditions.Fields where NCP Scale Inhibitors can be used are:Oil and Gas field
1-Water injection
2-Refineries
3-Water desalination
4-Power plants
5-Industrial waters

Mineral Scale

Mineral scales (subsequently referred to as scales) are inorganic solids precipitated from water and subsequently deposited. Scales are a common form of formation damage and blockages or restrictions to perforations, screens, liner or tubing.
Like most production chemistry problems, they pose a safety issue through loss of operability of check valves, safety valves or, in severe cases, tree valves. To predict the scaling potential of reservoir aquifer water, a representative water sample is required.
This requires that an appraisal or exploration well deliberately produces water, and that any contaminants such as completion or drilling fluids are also analyzed so that interference is backed out.
The water chemistry of hydrocarbon bearing reservoirs is highly variable, ranging from very low ion strength to high salinity brines containing a wide range of various ions.
Prevention and mitigation:
1.Mitigate or prevent scale in formation by using formation water instead of seawater,
2.Scale Inhibitor
Scales:
Hard inorganic crystals (~ 3 –4 mhos)
1-Slightly less than steel (5 mhos)
2-Diamond, 9 mhos
3-Variable crystal size
4-Microns to centimeters
5-Produced form aqueous solutions
6-Soluble in specially formulated solutions

Scale Types

The equilibrium that existed for so long is then upset on a geologically diminutive timescale during the production phase of the field development.
Production creates pressure and temperature reduction or introduces new fluids (muds, completion fluids or water injection).
The main types of scales are:
1-Carbonates–mainly calcium carbonate, but also iron carbonate
2-Sulphates–barium, strontium and calcium
3-Sulphide–less frequently encountered scales, but include lead, zinc and iron
4-Salts–mainly sodium chloride;
Most Common Types of Scales
1-Calcite (CaCO3)
–Formed due to the presence of calcium ions and bicarbonate ions in the produced water
–Pressure changes may cause precipitation

2-Barite (BaSO4)
–Generally formed when there is co-production of formation water (Ba2+) and injection water (SO4-)

Hydrogen Sulfide Gas Problems

Hydrogen sulfide is a colour less, flammable, poisonous gas that smells like rotten eggs.
Hydrogen Sulfide gas is very dangerous and in high concentrations is lethal and in low concentration gives a rotten eggs mell.
Hydrogen sulfide(or hydrogen sulphide) is the chemical compound with theformulaH2S. This colorless, toxic, flammable gas is partially responsible for the foul odor of rotten eggs and flatulence. It often results from the bacterial break down of sulfur-containing organic matter in the absence of oxygen, such as in swamp sand sewers (anaerobic digestion). It also occurs in volcanic gases,natural gas and some well waters. The body produces small amounts of H2S and uses it as a signaling molecule.

Safety

Hydrogen sulfide is a highly toxic and flammable gas. Being heavier than air, it tends to accumulate at the bottom of poorly ventilated spaces. Although very pungent at first, it quickly deadens the sense of smell, so potential victims may be unaware of its presence until it is too late. For safe handling procedures, a hydrogen sulfide material safety data sheet (MSDS)should be consulted.

Toxicity of H2S

Hydrogen sulfide is considered a broad-spectrum poison, meaning that it can poison several different systems in the body, although the nervous system is most affected. The toxicity of H2S is comparable with that of hydrogen cyanide. It forms a complex bond with iron in the mitochondrialcy to chromeenzymes, thereby blocking oxygen from binding and stop ping cellular respiration. Since hydrogen sulfide occurs naturally in the environment and the gut, enzymes exist in the body capable of detoxifying it by oxidation to (harmless) sulfate.Hence, low levels of sulfide may be tolerated indefinitely.
At some threshold level, believed to average around 300–350 ppm, the oxidative enzymes become overwhelmed. Many personal safety gas detectors, such as those used by utility, sewage and petrochemical workers, are set to alarm at as low as 5 to 10 ppm and to go into high alarm at 15 ppm.
Exposure to lower concentrations can result in eye irritation, a sore throat and cough, nausea, shortness of breath, and fluid in the lungs. These symptoms usually go away in a few weeks. Long-term, low-level exposure may result in fatigue, loss of appetite,headaches, irritability, poor memory, and dizziness. Chronic exposures to low level H2S (around 2ppm) has been implicated in increased miscarriage and reproductive health issues amongst Russian and Finnish wood pulp workers, but the reports have not (as of circa 1995) been replicated.

Toxicity of H2S in Details

0.0047ppmis the recognition threshold, the concentration at which 50% of humans can detect the characteristic odor of hydrogen sulfide, normally described as resembling "a rotten egg".
Less than 10 ppm has an exposure limit of 8 hours per day.
10–20 ppm is the borderline concentration for eye irritation.
50–100 ppm leads to eye damage.
At 150–250 ppm the olfactory nerve is paralyzed after a few inhalations, and the sense of smell disappears, often together with awareness of danger,
320–530 ppm leads to pulmonary edema with the possibility of death.
530–1000 ppm causes strong stimulation of the central nervous system and rapid breathing, leading to loss of breathing;
800 ppm is the lethal concentration for 50% of humans for 5 minutes exposure(LC50).
Concentrations over 1000 ppm cause immediate collapse with loss of breathing, even after inhalation of a single breath.
Hydrogen sulfide was used by the British as a chemical agent during World War One. It was not considered to be an ideal war gas, but while other gases were in short supply it was used on two occasions in 1916.The gas, produced by mixing certain household ingredients, was used in a suicide wave in 2008, primarily in Japan.