Drilling Rigs - PowerPoint by shabeerpary

VIEWS: 972 PAGES: 68


  Rotary Drilling Rigs
To familiarize the student with
  (1) the basic rotary drilling equipment and operational
  (2) introduce the student to drilling cost evaluation.

Drilling Team
    Large companies vs. small
    Specialized skills
    Service companies
Types of Wells
(1)   Wildcat Well: to discover new petroleum reservoir.
(2)   Development Well: exploit a known reservoir.
       Geological Group: recommends wildcat location.
       Reservoir Engg. Group: recommends development
       Drilling Group: designs and cost estimate.
       Tool pusher
       Driller
       Ass. Driller
       Derrickman (monkey board)
       2-3 rotary helpers (floormen – or – rough necks)
       Motor man
       Rig mechanics
                                       Types of Wells...

 Rig electrician
 Company man
 Roust abouts
 Head roust about is the crane operator
 Mud engineer
 Casing crew
 Cementing service
 Legal Group: secures drilling rights
 Surveyors: establish and stake well location
 Drilling Contractor (Bid basis)
 Cost per Foot – drilling in area is routine.
 Cost per Day – unknown area
 Location Preparation
 Water Wells
                                         Types of Wells...

• South Louisiana marshlands: inland barge

• Canadian Arctic Islands: man-made ice platform

• Extensive storage & Supply

• Manpower:        Contractor
                   Service Company
1.1 Types of Drilling Rigs
 Drilling and workover rigs come in a variety of shapes and
 sizes with each having its own characteristics suited for a
 particular job. Although there are many factors to be
 considered in selecting the best rig for the job, a few are
 especially critical. They are:
    Surface location (land, inland water, offshore)
    Estimated maximum hole depth
    Horsepower requirements
    Cost
    Availability
    As can be imagined, the selecting of drilling and workover
     rigs is best accomplished by use of good, sound judgement
     and engineering experience.

              Marine                                          Land

 Bottom                    FLoating           Conventional              Mobile

                   Semi/         Drill ship        Jacknife       Portable
                 Submersible                                     Mast (Small)

Platform      Barge    Jackup

    Self -      Tendered
Common Types of Drilling Rigs
1. Land Rigs
    As the name implies, these rigs are primarily used on
    land; however, some have been transported offshore for
    structure rig assignments. Most land rigs have to be
    transported to location in sections, but some are self-
    contained, permanently mounted on trucks. On location
    they are usually set up on a board mat with a substructure
    of 8 to 40 feet high, and a few are capable of drilling holes
    to 30,000+ feet.
2. Inland Barges
  Inland Barges are composed of two types:

  a.    Barge mounted rigs
       This type rig is capable of drilling in water depths from
       0 to 12 feet. After being towed on location, the rig’s
       hull is filled with water until it rests on bottom.

   b. Posted barge mounted rigs
     These type rigs have an upper deck supported by posts
     from the lower hull. The deck contains all drilling
     equipment and accommodations. Posted barges are
     capable of drilling in water depths from 0 to 20 feet.
     The rig is towed on location and the lower hull filled
     with water to secure it on bottom.
3. Submersible Rigs
    These rigs are towed on location and are capable of working
    in water depths from 18 to 70 feet. They are composed of an
    upper deck and lower hull connected by beams. On some
    types a large bottle, or something similar, is located on each
    corner of the rig for stability. These bottles, as well as the
    lower hull itself, are filled with water to set the rig on bottom
    and stabilize against movement.

4. Jack-up Rigs
    These rigs are normally towed on location, but a few are self-
    propelled. They are composed of an upper deck supported by
    either three or more legs attached to mats or spud cans and are
    capable of working in water depths from 30 to 350 feet.
    These mats or cans rest on the ocean floor with the deck
    jacked up into drilling position. There are two common types
    of jack-up rigs; Bethlehem and Letourneau. The former uses
    stabilized column legs attached to mats while the latter uses
    three, truss-type legs mounted on spudcans.
5. Semi-Submersible
     These rigs can be towed on location, or some types are self-
     propelled. They are capable of drilling in water depths of
     20 to 2,000+ feet. The rig itself remains stationary in the
     drilling position by a series of anchors (usually two
     connected at each corner of the rig) positioned on the ocean
     floor at a distance away from the rig. It should also be
     noted that some Semis can be used as a submersible rig.

6. Drill Ships
     Drill ships are self-propelled drilling vessels capable of
     drilling in water depths of 18 to 2,000+ feet. There are two
     basic types of drill ships - one that positions itself with
     anchors and one that uses dynamic positioning.
7. Structure Rigs
     Structure rigs are mounted on a fixed platform with all
     drilling equipment secured on deck. The rig itself is
     capable of changing positions on the structure;
     however, the structure is permanently based and
     designed to last many years. Structures are capable of
     being set in water depths of 10 to 850+ feet. Structure
     set-ups usually follow a successful exploratory program
     in order that many development wells can be drilled
     from one location. These wells are almost always
Rotary Drilling Process
• Rotary table rotates the drill string
 Downward force applied to the bit
 Cuttings are lifted to the surface by circulating a fluid
  down the drill string.

Main Component Parts of a Rotary Rig are:-
    1.   Power System
    2.   Hoisting System
    3.   Fluid Circulating System
    4.   Rotary System
    5.   Well Control System
    6.   Well Monitoring System
A Rotary Drilling Rig
1.2 Rig Power System

 Most power consumed by :
  hoisting system and fluid circulation

 Not used at same time

 Total power requirements 1000 – 3000 hp

 Old days steam

 Now internal combustion diesel engines types (1) diesel-
  electric type (electric motors), (2) direct-drive type (gears-
  chains) depending on power method.
Power-System Performance Characteristics
Are stated in terms of:

  1.     Output horse power
  2.     Torque
  3.     Fuel consumption for various engine speeds

  P      =      T = 2N.F.r                        (1.1)
  P      =     shaft power (hp)
        =     2N, Angular velocity of the shaft (engine speed), rad/min
  T      =     output torque (lb-ft)
  N      =     Rev./min
                     Power-System Performance Characteristics …...

 Overall power efficiency determines the rate of fuel
  consumption (Wf) at a given engine speed.
 Heating values (H Btu/lbm) of various fuels for internal
  combustion engines are shown in Table 1.1.
Fuel           Density (lbm/gal)         Heating Value H(Btu/lbm)
Diesel                  7.2                      19,000
Gasoline                6.6                      20,000
Butane                  4.7                      21,000
Methane                 --                       24,000

• Heat energy to the engine Qi
  Qi = Wf.H (hp)                                           (1.2)
  Et = P /Qi = Energy Output / Energy Input                (1.3)
  Et = overall power system efficiency
Example 1.1: A diesel engine gives an output torque of
  1,740 ft-lbf at an engine speed of 1,200 rpm. If the fuel
  consumption rate was 31.5 gal/hr, what is the output
  power and overall efficiency of the engine?

Solution:    The annular velocity, , is given by
             =2(1,200) = 7,539.8 rad/min.
  The power output can be computed using Eq. 1.1:
             P=  T
          7,539.8(1740) ft  lbf / min
                                      = 397.5 hp
              33,000 ft  lbf / hp
Since the fuel type is diesel, the density  is 7.2 lbm/gal
and the heating value H is 19,000 Btu/lbm (Table 1.1).
Thus, the fuel consumption rate is wf is
wf = 31.5 gal/hr (7.2 lbm/gal)
                                           1hour 
                                        60 min utes 

  = 3.78 lbm/min
The total heat energy consumed by the engine is given by Eq.
Qi= wf H
        3.78lbm / min(19,000 Btu / lbm)(779 ft  lbf / Btu)
                     33,000 ft  lbf / min/ hp

   = 1,695.4 hp.
Thus, the overall efficiency of the engine at 1,200 rpm given
by Eq. 1.3 is
         P   397.5
    Et           = 0.234 or 23.4% Answer
         Qi 1695.4
1.3 Hoisting System
   Used to lower or raise drill strings, casing string and other
   subsurface equipment into or out of hole.
 Principal Components:
   1. Derrick and substructure
   2. Block and tackle
   3. Draw works
 Functions of Derrick:
   1. Provides vertical height required to raise sections of pipe.
   2. Rated according to their ability to withstand compressive
       loads and (wind loads)
 Components of Block and Tackle:
   1. Crown block
   2. Travelling block
   3. Drilling line
Components of
the hoisting
Principal Function:
To provide a mechanical advantage which permits easier
handling of large loads.
       Load supported by travelling block
        Load imposed on the draw works
 M= Mechanical advantage
 F = tension in the fast line
 The ideal mechanical advantage that assumes no friction in
 the block and tackle can be determined from a force analysis
 of the travelling block.
                           n Ff= W
                          Mi =        n
                                 W /n
Input power of block and tackle = pi

      Pi = Ff Vf                                         (1.5)
      Ff = draw works load
      Vf = velocity of fast line
      Ph = output power of the hook load

      Pn = W.Vb                                          (1.6)
      W = travelling block load
      Vb = velocity of travelling block
         Vb 
         Vb 
            Ph ( nF f )  (V f / n )
         E                         1    no friction
            Pi        Ff V f
Power efficiency is
        E                  actual system
             Ff n

Tension in the fast line
      Ff                                        (1.7)
 Eq. 1.7 is used to select drilling line size.

 Fd       = W + Ff + Fs                          (1.8a)
 Fd       = load applied to the derrick
 Fs       = tension in the lead line
                 W W    1  E  En 
      Fd  W       W                        (1.8b)
                 En n       En     
             fast       dead
Example 1.2: A rig must hoist a load of 300,000 lbf. The
   drawworks can provide an input power to the block and
   tackle system as high as 500hp. Eight lines are strung
   between the crown block and traveling block.

(i) the static tension in the fast line when upward motion is
(ii) the maximum hook horsepower available,
(iii) the maximum hoisting speed,
(iv) the actual derrick load
(v) the maximum equivalent derrick load, and
(vi) the derrick efficiency factor.
Assume that the rig floor is arranged as shown in Fig 1.17.
(i) the power efficiency of n=8 is given as 0.841 in Table 1.2.
    The tension in the fast line is given by Eq. 1.7.
            W 300,000
       Ff              44,590lbf
            En 0.841(8)
(ii) The maximum hook horsepower available is
        Ph = E.I = 0.841 (500) = 420.5 hp

(iii) The maximum hoisting speed is given by

                            33,000 ft  lbf / min  
                   420.5hp                        
             P                       hp           
         vb  h                                     
                                                          = 46.3 ft/min
             W                300,000lbf
                                                     
                                                     
To pull a 90-ft stand would require
              90 ft
      t                  1.9 min
           46.3 ft / min
(iv) The actual derrick load is given by Eq. 1.8b
           1  E  En 
     Fd              W
               En     
          1  0.841  0.841(8) 
                               (300,000)
                                            = 382,090 lbf
                0.841(8)       
 (v) The maximum equivalent load is given by Eq. 1.9
               n4        84
         Fde         W        (300,000)  450,000lbf
                n            8
 (vi) The derrick efficiency factor is
                  Fd  382,090
                  F   450,000  0.849 or 84.9% Answer
            Ed      
                  de 
Provide the hoisting and braking power required to raise or
lower the heavy strings of the pipe.

Principle Parts
• The drums
• The brakes
• The transmission
• The catheads
 1.4 Rotary System
Main Parts:
 1. Swivel
 2. Kelly
 3. Rotary Drive
 4. Rotary Table
 5. Drill Pipe
 6. Drill Collar

1. Swivel:
        Supports the weight of the drillstring and permits
   rotation i.e. Bail and Gooseneck.

2. Kelly:
        Square or Hexagonal to be gripped easily. Torque is
   transmitting through kelly bushings. Kelly saver sub is
   used to prevent wear on the kelly threads.
                                                    Rotary System…...
3. Slips:
         During making up a joint slips are used to prevent
   drillstring from falling in hole.

4. Rotary Drive:
       Provides the power to turn the rotary table.
       * Power Sub: can be used to connect casing.
5. Drill Pipe:
        Specified by (a) Outer Diameter
                     (b) Weight per foot
                     (c) Steel grade
                     (d) Range Length
       Range                  Length (ft)

         1                    18 to 22
         2                    27 to 30
         3                    38 to 45
                                                    Rotary System…...
  * Tool Joint:     Female is called Box.
                    Male is called Pin.
  * Upset :         Thicker portion of the pipe.
  * Internal upset: Extra thick.
  * Thread Type:    Round, tungsten carbide hard facing.
6. Drill Collar:
   Thick walled heavy steel pipe used to apply weight to the bit.
   * Stabilizer Subs : Keep drill collars centralized.
   * Capacity : Volume per unit Length.

    Ap 
                d         = Capacity of pipe          (1.13)
    Aa        (d 2  d12 ) = Capacity of annulus
    As        (d1  d 2 ) = Displacement
                               Rotary System…...

Capacity and displacement nomenclature
                                                    Rotary System…...

Example 1.4: A drillstring is composed of 7,000 ft of 5-in.,
  19.5-lbm/ft drillpipe and 500 ft of 8-in. OD by 2.75-in ID
  drill collars when drilling a 9.875-in. borehole. Assuming
  that the borehole remains in gauge, compute the number
  of pump cycles required to circulate mud from the
  surface to the bit and from the bottom of the hole to the
  surface if the pump factor is 0.178 bbl/cycle.

  For field units of feet and barrels, Eq. 1.13 becomes

         2  2  gal  bbl  12in   d           
  Ap   d in.          
                       3 
                                   ft    1,029.4 bbl / ft
                                                   
       4      231in.  42 gal                 
                                                        Rotary System…...

Using Table 1.5, the inner diameter of 5-in., 19.5 lbm/ft
drillpipe is 4.276 in.; thus, the capacity of the drillpipe is
                            0.01766 bbl ft
  And the capacity of the drill collars is
                             0.00735 bbl ft
The number of pump cycles required to circulate new
mud bit is given by

               0.01776(7,000)  0.00735(500)bbl  719cycles.
                        0.1781 bbl cycle
                                                        Rotary System…...

Similarly, the annular capacity outside the drillpipe is given by

    9.8752  52
                0.0704 bbl ft
And the annulus capacity outside the drill collars is
     9.8752  82
                 0.0326 bbl ft
  The pump cycles required to circulate mud from the bottom
  of the hole to the surface is given by

        0.0704(7,000)  0.0326(500)  2,858cycles
              0.1781 bbl cycle
Components of the rotating system
 1.5 Circulating System
     1.       Mud Pumps
     2.       Mud Pits
     3.       Mud Mixing Equipment
     4.       Contaminants Removal Equipment
     Reciprocating Positive Displacement Piston Pumps.
       • Two-Cylinders - Duplex (Double Acting Forward-Backward)
       • Three-Cylinders - Triplex (Forward only Single Acting)

       Duplex                 Triplex
       Heavy                  Light
       Bulky                  More Compact
       High Output Pressure   Lower
       Pulsation              Without Pulsation
       Require more Maint.    Cheaper to Operate
Therefore majority of new pumps are Triplex.
                                                   Circulating System…...
  (1) Ability to move high solid content fluids
  (2) Ability to move large particles
  (3) Ease to operation and maintenance
  (4) Reliability
  (5) Ability to operate over wide range of pressure s and flow
  rates by changing the diameters of the pump liners and pistons.

Overall Pump Efficiency =Mechanical Efficiency x Volumetric Efficiency
        Em= Mechanical Efficiency ~ 90%
        Ev= Volumetric Efficiency ~ 100%

Two Circulating pumps are installed on the rig.
       • Shallow portion both are used.
       • Deeper portion one is used.
                               Circulating System…...

Components of the circulating System.
                     Circulating System…...

Circulating System
                                                         Circulating System…...

Pump Displacement

   (1) Double Acting
             Figure 1.25 (a)

dr = Piston rod diameter
dL= Liner diameter
Ls= Stroke Length (Stroke = one complete pump revolution).

Forward Stroke Volume Displaced = (/4) dL2 Ls
Backward Stroke Volume Displaced = (/4) (dL2 - dr2 ) Ls
                                                      (for one Cylinder)

Total Volume =Fp= 2 Ls(/4) (2LL2 - Lr2 ) . Ev                 (1.10)
                                                      (for two Cylinders)
        Fp= Pump factor or pump displacement cycle.
Example 1.3: Compute the pump factor in units of barrels
  per stroke for a duplex pump having 6.5-in. liners, 2.54-
  in. rods, 18-in. strokes and a volumetric efficiency of

  The pump factor for a duplex pump can be determined
  using Eq 1.10:

  Fp = 2 Ls(/4) (2LL2 - Lr2 ) . Ev
     = (/2) (18) [ 2(6.5)2 - (2.5)2] . (0.9)
     = 1991.2 in.3 /stroke
  or = 0.2052 bbl/stroke.            Answer
                                                        Circulating System…...
    (2) Triplex Acting
           Figure 1.25(b)

    Fp= 2 (/4) dL2 Ls. Ev                (1.11)
    q=flow rate = Fp . N
(Where N = no. of cycles per unit time)

Pumps are rated for
  1. Hydraulic Power
  2. Maximum Pressure
  3. Maximum Flowrate
                P  q
           PH                                                (1.12)
                       PH = Pump Pressure, hp
                       ∆P = Increase in pressure, psi
                       q = Flow rate (gal/min)
 ∆P cannot more than 3500 psi
                                             Circulating System…...

Flow conduits between pump and drill string include:

  1.   Surge chamber (Pulsation Damper)
  2.   4 or 6 inch heavy-walled pipe connecting the pump to
       a pump manifold located on the rig floor.
  3.   Standpipe and rotary hose.
  4.   Swivel
  5.   Kelly

Go over EXAMPLE 1.3.
                                                   Circulating System…...
    Contaminant Removal
  1.   Shale shaker for coarse rock cuttings
  2.   Hydrocyclones and decanting centrifuge for fine particles.
  3.   Degasser

Gas as a drilling Fluid (Air, Natural gas)
  1.   Penetration rate is higher than water especially when
       formation is strong and extremely low K.
  2.   Water flow is a problem.
  3.   Isolate by injecting
       (a) Low Viscosity Plastic
       (b) Silicon Tetrachloride
       (c) Using Packers
  4.   Min. annular velocity is 3000 ft/min for injection pressure.
  5.   Use Foam.
 1.6 Well Monitoring System
Parameters displayed
  1.    Depth
  2.    Penetration rate
  3.    Hook Load
  4.    Rotary Speed
  5.    Rotary Torque
  6.    Pump Rate
  7.    Pump Pressure
  8.    Mud Density
  9.    Mud Temperature
  10.   Mud Salinity
  11.   Gas content of mud
  12.   Hazardous gas content of air
  13.   Pit Level
  14.   Mud Flow Rate.

* Centralized well monitoring system
* Mud Logger
* Subsurface well-monitoring and data telemetry systems
  (mud pulser).
 1.7 Well Control System
  Prevents the uncontrolled flow of formation fluids from the

  Flow of formation fluids in the presence of drilling fluid

  1. Detect the Kick
  2. Close the well at the surface.
  3. Circulate the well under pressure to remove
      formation fluids and increase density.
  4. Move drillstring under pressure.
  5. Divert flow away from rig personnel and equipment.
Kick Detection During Drilling Operation
                                                Well Control System…...
Kick Detection:
  a. Pit volume indicator
  b. Flow indicator
  c. Hole fill up indicator (during tripping)
  d. Count the pump strokes.

BOP (Blow Out Preventer)
  Multiple BOP’S used in series: BOP Stack
Ram Preventers        Semi circular openings which
Pipe Rams             match diameter of pipe
Blind Rams :   Closes the hole, no pipe present.
Shear Rams:    Blind rams that shear the pipe.
               Working press: 2000, 5000, 10000, 15000 psig.
Annular Preventers (Bag-type): Rubber Ring
BOPE:Closed hydraulically or using screw-type locking.
                                              Well Control System…...

  High pressure hydraulic system used to close the BOP.
  * Fluid Capacity : 40, 80 120 gal.
  * Max. Operating Pressure : 1500-3000 psig.
  * has a small pump independent of rig power.

Strip Pipe
   Lower pipe with preventer closed. Must be able to vary
   closing pressure using pressure regulating system.

Drilling Spool
  Placed between ram preventers
  (1) provide space for stripping
  (2) flowline attached to it.
                                               Well Control System…...

Kill Line
   conduit used to pump into the annulus.
Choke Line            Conduit used to release fluid
Diverter Line         from the annulus.

Drilling Spools
  Must be large enough to allow next casing to be put in
  place without removing the BOP.

Casing Head (Braden Head)
  Attached to BOP, welded to the first string of casing
  cemented in the well.

Control Panel
  To operate the BOP stack. RSRRS
                                                  Well Control System…...
Rotating Head
  Seals around the kelly at top of BOP stack, used for drilling with
  slight surface pressure at annulus.
Kelly Cock
  Close the flow inside kelly.
Internal Blowout Preventers
   Prevents flow inside drill string.
Adjustable Choke
  Used during Kick circulation, controlled from a remote panel on
  the rig floor.
  Sufficient pressure must be held against the well by the choke so
  that the bottomhole pressure in the well is maintained slightly
  above the formation pressure.
  * Working Press Systems: 2000,3000,5000,10000,15000 psig.

To top