Well Control
Download
1 / 196

Well Control Principles - PowerPoint PPT Presentation


  • 101 Views
  • Uploaded on

Well Control Principles. Well Control Principles. Primary Well Control Secondary Well Control Tertiary Well Control Hydrostatic Pressure Formation Pressure Porosity And Permeability Kill Mud Density Indications of Increasing Formation Pressure. Well Control Principles.

loader
I am the owner, or an agent authorized to act on behalf of the owner, of the copyrighted work described.
capcha
Download Presentation

PowerPoint Slideshow about ' Well Control Principles' - nita


An Image/Link below is provided (as is) to download presentation

Download Policy: Content on the Website is provided to you AS IS for your information and personal use and may not be sold / licensed / shared on other websites without getting consent from its author.While downloading, if for some reason you are not able to download a presentation, the publisher may have deleted the file from their server.


- - - - - - - - - - - - - - - - - - - - - - - - - - E N D - - - - - - - - - - - - - - - - - - - - - - - - - -
Presentation Transcript

Well Control

Principles


Well Control Principles

  • Primary Well Control

  • Secondary Well Control

  • Tertiary Well Control

  • Hydrostatic Pressure

  • Formation Pressure

  • Porosity And Permeability

  • Kill Mud Density

  • Indications of Increasing Formation Pressure


Well Control Principles

  • The function of Well Control can be subdivided into 3 main categories:

    • Primary Well Control: is the use of the fluid to prevent the influx of formation fluid into the well bore.

    • Secondary Well Control: is the use of the BOP to control the well if Primary WC can not be maintained.

    • Tertiary Well Control: squeeze back, cement ...


The Well is Balanced:

when Hydrostatic Pressure = Formation Pressure


The Well is Under Balanced:

when Hydrostatic Pressure < Formation Pressure


The Well is Over Balanced:

when Hydrostatic Pressure > Formation Pressure


Hydrostatic Pressure

Because the pressure is measured in psi and depth is measured in feet, it is convenient to convert Mud Weight from ppg to a pressure gradient in psi/ft.

The conversion factor is 0.052

Fluid Density (ppg) x 0.052 = Pressure gradient (psi/ft)

Hydrostatic Pressure is the pressure exerted by a column of fluid at rest, and is calculated by multiplying the gradient of the fluid by the True Vertical Depth at which the pressure is being measured:

Fluid gradient (psi/ft) x TVD = Hyd. Pressure(psi)


T V D

You have to consider the vertical height or depth of the fluid column, the shape of the hole doesn’t matter.


Normal Formation Pressure

Normal formation pressure is equal to the hydrostatic pressure of the water occupying the pore spaces from the surface to the subsurface formation.

Native fluid is mainly dependent on its salinity and is often considered to be: 0.465 psi/ft


Abnormal Formation Pressure

Abnormal formation pressures are any formation pressures that are greater than the hydrostatic pressure of the water occupying the pore spaces.

Commonly caused by the under-compaction of shale’s, clay-stone or faulting...


Subnormal Pressure: is defined as any formation pressure that is less than “normal” pressure.

It can be due to reservoir depletion,fault …

Transition Zone: is the formation in which the pressure gradient begins to change from a normal gradient to a subnormal gradient or, more usually, to an abnormal gradient.


UNDERCOMPACTED SHALES / SAND.

UNCONSOLIDATED

SHALE-DENSITY INCREASES WITH DEPTH - WATER ESCAPES

SAND WITH COMMUNICATION TO SURFACE

SHALE-DENSITY DECREASES WITH DEPTH-WATER ENCLOSED

ENCLOSED SAND LENS WITH FORMATION FLUID


GAS CAP

NORMAL FORMATION

PRESSURE ABOVE CAP

ROCK =0.465 PSI/FT

Ph

Pabnormal = Pf-Pg

Pf

Pg

GAS PRESSURE

GRADIENT = 0.1 PSI/FT

COMMUNICATION BETWEEN FLUID AND GAS



NATURALLYSURCHARGED FORMATIONS

FAULT ZONE

Pf

Pf


ARTESIAN WELL

NORMAL FORMATION

PRESSURE AT THE WELL

UNTILL BELOW THE CAP

ROCK

LAKE

HYDROSTATIC

PRESSURE

FROM

FORMATION

WATER

COLUMN

POROUS SANDSTONE

BELOW CAP ROCK


SURFACE EROSION

ENCLOSED FORMATION

LEVEL CHANGE

H1

H3

Pf

H2

Pf

Pf


Porosity & Permeability

The essential properties of reservoir rocks are:

- Their porosity and permeability.

Theporosity provides the storage space for fluids and gases and is

the ratio of the pore spaces in the rock to the bulk volume of the rock.

This is expressed as a percentage. Reservoir rocks commonly have

porosity’s ranging from 5% to 30%.

Formation permeability is a measure of how easy the fluid will flow

through the rock. Permeability is expressed in Darcys, from a few

milliDarcys to several Darcys.

These properties will determine how much and how quick a kick will enter into the well. Kicks will enter a wellbore faster from rocks having high permeability.


Tiny openings in rock are pores Porosity

Pores are connected for the Permeability


Formation Pressure

When the well is shut in, Formation Pressure can be found with the following formula:

SIDPP + Hydrostatic pressure = Formation Pressure

SICP + Influx Hyd + Mud Hyd = Formation Pressure

SICP

+

Mud Hydrostatic

+

Influx Hydrostatic

=

SIDPP

+

Mud Hydrostatic

=

Formation Pressure



POSITIVE KICK SIGNS

Positive Indications of a kick:

- Flow from Well (pumps off)

- Increase in Flow from Well (pumps on)

- Pit Volume Gain


KICKS WHILE TRIPPING

Incorrect Fill or Return Volumes

- Swabbing

- Surging

If any deviation, the FIRST action will be to install a fully open safety valve and make a Flow-Check.

Remember: It is possible that the well will not flow even if an influx has been swabbed in.


KICKS WHILE DRILLING

Early Warning Signs

That the well MIGHTbe going under-balanced


Indications of Increasing Formation Pressure

  • Increase in Drilling Rate

  • Change in D - Exponent

  • Change in Cutting size and shape

  • Increase in Torque and Drag

  • Chloride Trends

  • Decrease in Shale Density

  • Temperature Measurements

  • Gas Cut Mud

  • Connection Gas


ROP

Depth

Increase in Drilling Rate:

While drilling normally pressured shale and assuming a fairly constant bit weight, RPM, and hydraulic program, a normal decrease in penetration rate can be expected. When abnormal pressure is encountered, differential pressure and shale density are decreased causing a gradual increase in penetration rate.


Torque

Depth

Increase in Torque and Drag

Increase in torque and drag often occurs when drilling under balanced through some shale intervals.

There is a build up of cuttings in the annulus and this may be a sign that pore pressure is increasing.


“d”

Depth

Change in “d” Exponent:

“d” is an indication of drill ability and ROP, RPM, WOB, bit size are used to calculate its value.

Trends of “d” normally increase with depth, but in transition zones, it may decrease with lower than expected value.


Change in cutting size and shape

Normally pressured shale: cuttings are small with rounded edges, generally flat.

Abnormally pressured shale: cutting are long and splintery with angular edges.

As differential between the pore pressure and bottom pressure is reduced, the cuttings have a tendency to “explode” of bottom.


Chloride

Depth

Chloride Trends:

The chloride content of the mud filtrate can be monitored both going into and coming out of the hole.

A comparison of chloride trends can provide a warning or confirmation signal of increasing pore pressure.


Shale

Density

Depth

Decrease in Shale Density:

Shale density normally increases with depth but decreases as abnormal pressure zones are drilled.

When first deposited, shale has a high porosity. During normal compaction, a gradual reduction in porosity occurs with an increase of the overlaying sediments.


Temp.

Depth

Temperature Measurements:

The temperature gradient in abnormally pressured formations is generally higher than normal.


Gas Cut Mud

The presence of gas cut mud does not indicate that the well is kicking ( gas may have been entrained in the cutting ). However, the presence of gas cut mud must be treated as an early warning sign of a potential kick.

- Gas cut mud only slightly reduces mud column pressure, when it is close to surface.

- Drilled cuttings from which the gas comes may compensate for the decrease.


Connection Gas

Connection gas are detected at the surface as a distinct increase above the background gas, as bottom up is circulated after a connection.

Connection gases may indicate a condition of near balance.

If connection gas is present, limiting its volume by controlling the drilling rate should be considered.


System pressure losses

SYSTEM PRESSURE LOSSES


Objectives

  • Identify the different pressures losses in the system

  • Identify which one influence bottom hole pressure

  • Convert this pressure to an equivalent mud weight


Mud system pressure losses

100 psi

0 psi

100 psi

Mud System Pressure Losses

  • Pumping through a pipe with a mud pump at 80 spm, with gauges mounted on the discharge of the pump and at the end of the pipe.

  • The gauge on the pump reads 100 psi.

  • The gauge on the end of the pipe reads 0 psi.

  • It can be assumed from this information that the 100 psi drop in pressure through the pipe is the result of friction losses in the pipe as the fluid is pumped through it.

80 SPM


500 psi

400 psi

100 psi

400 psi

0 psi

Mud System Pressure Losses

80 SPM


Mud System Pressure Losses

1000 psi

900 psi

100 psi

80 SPM

400 psi

500 psi

500 psi

0 psi


2300 psi

2200 psi

100 psi

400 psi

1800 psi

500 psi

1300 psi

1300 psi

Mud System Pressure Losses

80 SPM

0 psi


Mud System Pressure Losses

2600 psi

2500 psi

0 psi

100 psi

80 SPM

Annular

Pressure

Losses

400 psi

300 psi

2100 psi

500 psi

1600 psi

1300 psi

300 psi


Apl example

MUD WT = 10 ppg

10,000 ft TVD

Mud System Pressure Losses

APLEXAMPLE

0 psi

0 psi

0 psi

  • A well has been drilled to10,000 ft.

  • The mud weight is 10 ppg.

  • To find our Hydrostatic pressure we use the following formula;

  • Mud Wt x 0.052 x TVD 10 x 0.052 x 10,000 = 5,200psi.

  • The gauge on the drawing shows bottom hole hydrostatic pressure.

0 SPM

0 psi

0 psi

5200 psi


Apl example1

2600 psi

2500 psi

100 psi

0 psi

MUD WT = 10 ppg

400 psi

10,000 ft TVD

300 psi

2100 psi

500 psi

1600 psi

1300 psi

5500 psi

Mud System Pressure Losses

APL EXAMPLE

  • If we now start to circulate at 80 spm through our system with the same pressure losses as before.

  • As you can see from this example the bottom hole pressure has increased by 300 psi.

  • This increase is due to the Annular Pressure Losses (APL) acting down on the bottom of the well and is usually called “Bottom Hole Circulating Pressure” (BHCP)

80 SPM


Equivalent circulating density

The APL while circulating has the same effect on bottom hole pressure as increasing the mud weight.

This theoretical increase in mud weight is called the Equivalent Circulating Density or Equivalent Mud Weight.

It can be calculated by using the following formula:

_____APL(psi) __ + Original Mud Weight

TVD x 0.052

Equivalent Circulating Density


Summary: pressure as increasing the mud weight.

  • Annular Pressure Losses are the pressure losses caused by the flow of fluid up the annulus and are the only losses in the system that affect BHP.

  • Equivalent Circulating Density is the effective density at any depth created by the sum of the total hydrostatic plus the APL.


300 psi pressure as increasing the mud weight.

600 psi

450 psi

800 psi

1200 psi

Exercise

- Pressure Gradient?

- Hydrostatic Pressure?

- Pump Pressure @ 40 spm?

- A P L?

- ECD at 40 SPM?

40 SPM

MUD WT = 12 ppg

MD = 9,550 ft

TVD = 8,000 ft


Effects on pressures

EFFECTS ON PRESSURES pressure as increasing the mud weight.


Mud weight change
MUD WEIGHT CHANGE pressure as increasing the mud weight.

2600 psi

  • A well is being drilled using 10 ppg mud. At 80 spm the total circulating system pressure losses are 2600 psi.

  • It is decided to increase the mud weight to 11 ppg.

80 spm

Mud wt 10 ppg


Mud weight change1
MUD WEIGHT CHANGE pressure as increasing the mud weight.

2860 psi

It is a good drilling practice to calculate the new circulating pressure before changing the mud weight.

The way we calculate this change in pressure is to use the following formula;

New Mud ppg x Old psi.

Old Mud ppg

11 ppg x 2600 = 2860psi

10 ppg

The new pump pressure would be approximately 2860 psi.

80 spm

Mud wt 11 ppg


Final circulating pressure
Final Circulating Pressure pressure as increasing the mud weight.

  • The formula that was just used to calculate the pressure change due to a change in mud weight, is also the formula used to calculate the Final Circulating Pressure.

    Kill Mud wt x Slow circulating rate press .

    Old Mud wt


Pump stroke change
PUMP STROKE CHANGE pressure as increasing the mud weight.

2600 psi

  • A well is being drilled using 10 ppg mud. At 80 spm the total circulating system pressure losses are 2600 psi.

  • It is decided to increase the pump speed from 80 spm to 100 spm.

80 spm

Mud wt 10 ppg


Pump stroke change1
PUMP STROKE CHANGE pressure as increasing the mud weight.

4063 psi

  • It is a good drilling practice to calculate the new circulating pressure before changing the pump speed.

  • The way we calculate this change in pressure is to use the following formula;

  • New SPM 2 Old psi x Old SPM

  • 2600 x 100 spm 2 80 spm = 4063 psi

  • The new pump pressure would be approximately 4063 psi.

100 spm

Mud wt 10 ppg


Preparation pressure as increasing the mud weight.

and

Prevention


Preparation and Prevention pressure as increasing the mud weight.

  • Barite and Mud chemical stocks

  • Equipment line up for shut-in

  • Slow circulating rates

  • M A A S P

  • Well Control Drills

  • Flow Checks

  • Safety Valves and Float Valves


LINE UP FOR pressure as increasing the mud weight.

HARD SHUT IN

FLOWPATH


HARD SHUT IN pressure as increasing the mud weight.

1

Pick off bottom and position string

Stop pumps & Rotation

Close BOP (Ram or Annular)

Open hydraulic side outlet valve

Observe pressure

2

3

5

4

1

5

2

4

3

FLOWPATH


LINE UP FOR pressure as increasing the mud weight.

SOFT SHUT IN

FLOWPATH


SOFT SHUT IN pressure as increasing the mud weight.

1

Pick off bottom and position string

Stop pumps & Rotation

Open hydraulic side outlet valve

Close BOP (Ram or Annular)

Close remote hydraulic choke

Observe pressure

2

3

6

5

4

1

5

6

2

3

4

FLOWPATH


Slow Circulating Rate pressure as increasing the mud weight.

  • A Slow Circulating Rate ( SCR) is the reduced circulating pump rate that is used when circulating out a kick.

  • It is called Dynamic Pressure Losses ( PL ) on the kick sheet


Well control operations are conducted at reduced circulating rates in order to

Slow Circulating Rate pressure as increasing the mud weight.

Well Control Operations are conducted at reduced circulating rates in order to:

  • Minimise Excess of annulus pressure

  • Allows for more controlled choke adjustments

  • Allows for the weighting up and degassing of the mud and disposal of the influx

  • Reduce the chance of choke erosion

  • Reduce risk of over pressuring system if plugging occurs


Scr s pressure for each pump will be taken

Slow Circulating Rate pressure as increasing the mud weight.

SCR’s pressure for each pump will be taken:

  • If practical, at the beginning of every tour

  • Any time the mud properties are changed

  • When a bit nozzle is changed.

  • When the BHA is changed.

  • As soon as possible after bottoms-up from any trip

  • At least every 1000 feet (305m) of new hole


Slow Circulating Rate pressure as increasing the mud weight.

  • A minimum of 2 (two) circulating rates should be obtained for all pumps.

  • The pressure must be recorded using the gauges that will be used during well kill operations

  • The SCR pressure will be recorded on the IADC report


Formation Strength Test or LOT pressure as increasing the mud weight.

A leak off test (LOT) determines the pressure at which the formation begins to take fluid.

This test is conducted after drilling out about 10 to 15 ft of new hole below the shoe.

Such a test will establish the strength of the formation and the integrity of the cement job at the shoe.

The test pressure should not exceed 70% of the minimum yield of the weakest casing.


L O T pressure as increasing the mud weight.

Use a high pressure, low volume pump (0.25 - 0.5 bbl/min.) such as a cement pump or a test pump using intermittent or continuous method of pumping.

Rig pumps are not suitable to perform leak off tests.

The objective of the above test is not to fracture the formation, but rather to identify the “formation intake pressure”.

This “intake pressure” is identified as that point where a deviation occurs between the trends of the final pump pressure curve and the static pressure curve. Once the formation intake pressure has been reached, further pumping should be avoided.


L O T pressure as increasing the mud weight.

The total pressure applied at the shoe is the sum ofthe surface pressure from the pump and the hydrostatic pressure for the shoe depth.

This total pressure is applied to the formation.

Surface Casing Pressure

+ Hydrostatic Pressure

=

Pressure at Shoe


L O T pressure as increasing the mud weight.

720 psi

720 psi

+

1498 psi

9.6 ppg

3,000’

2218 psi

This total pressure is applied to the formation.


0 psi pressure as increasing the mud weight.

3,000’

2218 psi

M A M W

The Maximum Available Fluid Density (MAMW).

This is the total pressure, represented as fluid density, above which leak off or formation damage may occurs with no pressure on surface.

MAMW = 14.2 ppg

MAMW= 2218

3000 x 0.052


0 psi pressure as increasing the mud weight.

3,000’

2218 psi

Fracture Gradient

The fracture gradient of the formation will be:

Fracture gradient = MAMW x 0.052

Fracture Gradient = 14.2 x 0.052

= 0.7384 psi/ft

therefore:

MAMW = Fracture Gradient / 0.052


Maximum Allowable Annular Surface pressure pressure as increasing the mud weight.

M A A S P

MAASP is defined as the surface pressure which, when added to the hydrostatic pressure of the existing mud column, results in formation breakdown at the weakest point in the well.

This value is based on the Leak Off Test data.


Write leak off test pressure here pressure as increasing the mud weight.

Write mud weight used for the test

Calculate maximum allow mudweight

and Insert here

Calculate current MAASP and insert here

On Kill Sheet


Drills
Drills pressure as increasing the mud weight.

  • Pit drill

  • Trip drill

  • Abandonement drill

  • Strip drill


Actions pressure as increasing the mud weight.

Upon

Taking a Kick


  • Causes for the Loss of Primary Well Control pressure as increasing the mud weight.

  • Kick Size and Severity

  • Kick Detection

  • Recording Pressures

  • Drilling With Oil Base Mud

  • Hard Shut-in

  • Soft Shut-in

  • Height and Gradient of a Kick


Causes for the loss of Primary Well Control pressure as increasing the mud weight.

  • Failure to Fill The Hole Properly While Tripping

  • Swabbing / Surging

    • High pulling speed

    • Mud properties

    • Tight annulus clearance

    • Well Geometry

    • Formation Properties

  • Lost Circulation

  • Insufficient Drilling Fluid Density


  • Kick Size and Severity pressure as increasing the mud weight.

    Minimizing kick size is fundamental for the safety of a Well Control operation.Smaller Kicks:Provide lower choke or annulus pressure both upon initial closure and later when the kick is circulated to the choke.

    • ControllableParameters:Youcaninfluenceon:

    • Degree of underbalance Mud Weight

    • Length of reservoir exposed ROP + Kick detection time

    • Time well remains underbalanced Kick detection + shut-in time

    • Wellbore diameter Hole size

    • Non-controllable Parameters

    • Formation permeability and type of influx


    Kick Detection pressure as increasing the mud weight.

    • While Drilling:

    • Drilling breaks: They will be flow checked. Circulating B/up is advisable if F/C is negative. Tool pusher must be informed for all.

    • Increase in flow rate: First positive indicator.

    • Increase in pit volume: Positive indicator. Anyone influencing the active system must communicate with the Driller.

    • Variation in Pump speed and Pressure: (“U-tube”)

    • Well flowing during a Connection: ECD to ESD

    • Change of drilling fluid properties: Gas cut or fluid contaminated.

    • While Tripping:

    • Improper fill-up: swabbing or surging


    Shut- in Procedure: pressure as increasing the mud weight.HARD SHUT-IN

    • Stop rotation

    • Pick up the drill string to shut-in position (subsea to hang off position)

    • Stop the pump

    • Flow check

    • If the well flows

    • Close BOP

    • Open remote control choke line valve

    • Notify Tool Pusher and OIM

    • Record time, SIDPP, SICP and pit gain


    Shut- in Procedure: pressure as increasing the mud weight.SOFT SHUT-IN

    • Stop rotation

    • Pick up the drill string to shut-in position (Subsea to hang off position)

    • Stop the pump

    • Flow check

    • If the well flows

    • Open remote control choke line valve

    • Close BOP

    • Close choke

    • Notify Tool Pusher

    • Record time, SIDPP, SICP and pit gain


    Close in methods specified by american petroleum institute

    Soft close-in procedure pressure as increasing the mud weight.

    For a soft close-in, a choke is left open at all times other than during a well control operation. The choke line valves are aligned such that a flow path is open through the choking system, with the exception of one choke line valve located near the blow out preventer. When the soft close-in procedure is selected for closing in a well the:

    1 choke line valve is opened.

    2 Blow out preventer is closed.

    3 Choke is closed.

    This procedure allows the choke to be closed in such a manner to permit sensitive control and monitoring of casing pressure buildup during closure.

    Hard close-in procedure

    For a hard close-in, the chokes remain closed at all times other than during a well control operation. The choke line valves are aligned such that a flow path is open through the choking system with the exemption of the choke(s) itself and one choke line valve located near the blow out preventer stack. When the hard close-in procedure is selected for closing in a well, the blow out preventer is closed. If the casing pressure cannot be measured at the well head, the choke line valve is opened with the choke or adjacent high pressure valve remaining closed so that pressure can be measured at the choke manifold. This procedure allows the well to be closed in the shortest possible time, thereby minimising the amount of additional influx of kicking fluid to enter the well bore.

    Close-in Methods specified byAmerican Petroleum Institute


    Surface Pressure After Shut-in pressure as increasing the mud weight.


    OIL BASE MUD pressure as increasing the mud weight.


    Drilling with OBM pressure as increasing the mud weight.


    Gas Influx in WBM or in OBM pressure as increasing the mud weight.

    • Water Base Mud

    • Easier to detect

    • Higher migration rate

    • Gas stay as a separate phase

    • On bottom bigger kick size

    • Higher casing pressure

    • Expansion:

    • - Slow first then Fast

    • Oil Base Mud

    • More difficult to detect

    • Lower migration rate

    • Gas go into solution

    • On bottom smaller kick size

    • Smaller casing pressure

    • Expansion:

      • - none first then very fast at the bubble point


    Height and Gradient of a Kick pressure as increasing the mud weight.


    Well Kill pressure as increasing the mud weight.

    Techniques


    • Driller’s Method pressure as increasing the mud weight.

    • Wait and Weight Method

    • Volumetric Method


    Well Kill Techniques pressure as increasing the mud weight.


    Driller’s Method : pressure as increasing the mud weight.1 st Circulation

    The original mud weight is used to circulate the influx

    - Reset the stroke counter.

    - Bring the pump up to kill speed while holding the casing pressure constant.

    - Maintain DP pressure constant until the influx is circulated out from the well

    BHP


    Driller’s Method : pressure as increasing the mud weight.1 st Circulation

    The maximum shoe pressure is when the top of the influx reaches the shoe


    Driller’s Method : pressure as increasing the mud weight.1 st Circulation

    When the influx is passing the casing shoe, the shoe pressure will decrease.


    Driller’s Method : pressure as increasing the mud weight.1 st Circulation

    When the influx is above the casing shoe, the shoe pressure will remain constant.


    Driller’s Method : pressure as increasing the mud weight.1 st Circulation

    - Surface casing pressure is increasing as the influx is circulated up the well.

    - Pit volume is raising.


    Driller’s Method : pressure as increasing the mud weight.1 st Circulation

    - The maximum surfacecasing pressure is reached when the top of the influx is at surface.

    - It will be the maximum increase in pit level.


    Driller’s Method : pressure as increasing the mud weight.1 st Circulation

    - As the influx is passing through the choke, the surface casing pressure will decrease.

    - The pit volume will decrease.


    Driller’s Method : pressure as increasing the mud weight.1 st Circulation

    If all the influx is successfully circulated from the well and the pump is stopped,

    SIDPP = SICP


    Driller’s Method : pressure as increasing the mud weight.2 nd Circulation

    - Line up the kill mud.

    - Reset the stroke counter.

    - Bring the pump up to kill speed while holding the casing pressure constant.

    - Reset the stroke counter after pumping the surface line volume.

    - Keep the casing pressure constant until KMW reach the bit.

    ( Or follow the calculated DP pressure drop schedule from ICP to FCP.)

    Pit volume has increased due to the weighting material added in the system.


    Driller’s Method : pressure as increasing the mud weight.2 nd Circulation

    When kill mud enters the annulus, maintain FCP constant until kill mud is at surface.


    First Circulation pressure as increasing the mud weight.

    Driller’s

    Method

    Drill Pipe

    Driller’s

    Method

    Casing


    Second Circulation pressure as increasing the mud weight.

    Driller’s

    Method

    Drill Pipe

    Driller’s

    Method

    Casing


    Driller’s Method pressure as increasing the mud weight.

    Advantages:

    - Can start circulating right away

    - Able to remove influx even if not enough barite on board

    - Less chance of gas migration

    - Less calculation

    Disadvantages:

    - Higher surface pressure

    - In certain situation, higher shoe pressure

    - Two circulation, more time through the choke


    Wait and Weight pressure as increasing the mud weight.

    -The kill mud weight is used to circulate the influx

    -Reset the stroke counter

    - Bring the pump up to kill speed while Holding the casing pressure constant.

    - Reset the stroke counter after pumping the surface line volume.

    -Pump kill mud from surface to bit while following a calculated DP pressure drop schedule.

    BHP


    Wait and Weight pressure as increasing the mud weight.

    When kill mud enters the annulus, maintain FCP constant until kill mud is at surface.


    One Circulation Only pressure as increasing the mud weight.

    Wait

    &

    Weight

    Drill Pipe

    Wait

    &

    Weight

    Casing


    Wait & Weight Method pressure as increasing the mud weight.

    Advantages:

    - Can generate lower pressure on formation near the casing shoe

    - In most situation generate less pressure on surface equipment

    - With a long open hole, less chance to induce losses

    - One circulation, less time spent circulating through the choke

    Disadvantages:

    - Longer waiting time prior to circulate the influx

    - Cutting could settle down and plug the annulus

    - Gas migration might become a problem

    - Need to have enough barite to increase the mud weight

    - More Calculations


    Differences pressure as increasing the mud weight. between W&W and Driller’s methods

    h'i

    h'i

    W & W Method

    Gas at Casing Shoe,

    kill mud in drill string

    hm

    hm

    Drillers Method

    Gas at Casing Shoe


    Differences pressure as increasing the mud weight. between W&W and Driller’s methods

    h'i

    h''i

    W & W Method

    Gas at Casing Shoe,

    Kill mud in annulus

    hm

    Drillers Method

    Gas at Casing Shoe

    hm

    hkm


    Gas Behavior pressure as increasing the mud weight.

    • Free gas expansion

    • No gas expansion

    • Volume to bleed off to maintain BHP constant


    Free Gas Expansion pressure as increasing the mud weight.

    Gas may be swabbed into a well and remain at TD. The influx will expand as it moves up the annulus when circulation is started. The amount of expansion can easily be calculated. If undetected, free gas expansion can cause a serious well control problem.


    Free Gas Expansion pressure as increasing the mud weight.

    A column of 10,000ft of mud, Gm=0.5psi/ft compresses one barrel of gas at TD.

    The pressure in the gas is;

    10,000 x 0.5 = 5,000 psi

    Multiply P x Vg to find the constant.

    D=10,000ft

    Gm = 0.5 psi/ft

    Gas

    D

    10,000

    P

    5,000

    Vg

    1

    5,000

    CST


    Free Gas Expansion pressure as increasing the mud weight.

    The gas has risen so that the top of the bubble is at 5,000ft from the surface.

    The pressure in the gas is;

    5,000 x 0.5 = 2,500 psi

    Using the constant, the volume of gas is found:

    5,000 / 2,500 = 2 barrels

    D=5,000ft

    Gm = 0.5 psi/ft

    D

    10,000

    5,000

    5,000

    2,500

    P

    Vg

    1

    2

    5,000

    5,000

    PVg


    Free Gas Expansion pressure as increasing the mud weight.

    The top of the bubble is at 2,500ft from the surface.

    The pressure in the gas is;

    2,500 x 0.5 = 1,250 psi

    The volume of gas is found:

    5,000 / 1,250 = 4 barrels

    D=2,500ft

    Gm = 0.5 psi/ft

    D

    10,000

    5,000

    2,500

    P

    5,000

    2,500

    1,250

    Vg

    1

    2

    4

    PVg

    5,000

    5,000

    5,000


    D pressure as increasing the mud weight.

    10,000

    5,000

    2,500

    1,250

    P

    5,000

    2,500

    1,250

    625

    Vg

    1

    2

    4

    8

    5,000

    PVg

    5,000

    5,000

    5,000

    Free Gas Expansion

    At 1,250ft from the surface.

    Pressure;

    1,250 x 0.5 = 625 psi

    Volume of gas;

    5,000 / 625 = 8 barrels

    D=1,250ft

    Gm = 0.5 psi/ft


    D pressure as increasing the mud weight.

    10,000

    5,000

    2,500

    1,250

    0

    P

    5,000

    2,500

    1,250

    625

    14.7

    Vg

    1

    2

    4

    8

    341

    PVg

    5,000

    5,000

    5,000

    5,000

    5,000

    Free Gas Expansion

    Gm = 0.5 psi/ft


    No Gas Expansion pressure as increasing the mud weight.

    0 psi

    0 ft

    2,500 ft

    5,000 ft

    7,500 ft

    1 bbls

    10,000 ft

    5,200 psi

    Gm = 0.52 psi/ft

    1 bbl gain


    No Gas Expansion pressure as increasing the mud weight.

    0 psi

    1,300 psi

    0 ft

    2,500 ft

    5,000 ft

    7,500 ft

    1 bbls

    1 bbls

    10,000 ft

    5,200 psi

    6,500 psi

    Gm = 0.52 psi/ft

    1 bbl gain

    1 bbl gain


    No Gas Expansion pressure as increasing the mud weight.

    0 psi

    1,300 psi

    2,600 psi

    0 ft

    2,500 ft

    1 bbls

    5,000 ft

    7,500 ft

    1 bbls

    1 bbls

    10,000 ft

    5,200 psi

    6,500 psi

    7,800 psi

    Gm = 0.52 psi/ft

    1 bbl gain

    1 bbl gain

    1 bbl gain


    0 psi pressure as increasing the mud weight.

    1,300 psi

    2,600 psi

    3,900 psi

    No Gas Expansion

    0 ft

    2,500 ft

    1 bbls

    1 bbls

    5,000 ft

    7,500 ft

    1 bbls

    1 bbls

    10,000 ft

    5,200 psi

    6,500 psi

    7,800 psi

    9,100 psi

    Gm = 0.52 psi/ft

    1 bbl gain

    1 bbl gain

    1 bbl gain

    1 bbl gain


    0 psi pressure as increasing the mud weight.

    1,300 psi

    2,600 psi

    3,900 psi

    5,200 psi

    No Gas Expansion

    0 ft

    1 bbls

    2,500 ft

    1 bbls

    1 bbls

    5,000 ft

    7,500 ft

    1 bbls

    1 bbls

    10,000 ft

    5,200 psi

    6,500 psi

    7,800 psi

    9,100 psi

    10,400 psi

    Gm = 0.52 psi/ft

    1 bbl gain

    1 bbl gain

    1 bbl gain

    1 bbl gain

    1 bbl gain


    500 psi pressure as increasing the mud weight.

    1800 psi

    500 psi

    Volume to bleed off to keep BHP constant

    0 ft

    2,500 ft

    5,000 ft

    5700 psi

    4400 psi

    1.3bbls

    7,500 ft

    1bbls

    P1V1 = P2V2

    V2 = 5700 x 1 / 4400

    V2 = 1.29 bbls

    2500 x .52 = 1300 psi

    1 bbls

    10,000 ft

    5,700 psi

    7000 psi

    5,700 psi

    Gm = 0.52 psi/ft

    1 bbl gain

    1 bbl gain

    1.3 bbl gain


    500 psi pressure as increasing the mud weight.

    1800 psi

    500 psi

    Volume to bleed off to keep BHP constant

    0 ft

    2,500 ft

    3100 psi

    4400 psi

    1.84bbls

    5,000 ft

    1.3bbls

    P1V1 = P3V3

    V3 = 5700 x 1 / 3100

    V3 = 1.84 bbls

    1.3 bbls

    7,500 ft

    5000 x .52 = 2600 psi

    10,000 ft

    5,700 psi

    7,000 psi

    5,700 psi

    Gm = 0.52 psi/ft

    1.3 bbl gain

    1.3 bbl gain

    1.84 bbl gain


    500 psi pressure as increasing the mud weight.

    1800 psi

    500 psi

    Volume to bleed off to keep BHP constant

    0 ft

    3100 psi

    1800 psi

    2,500 ft

    1.8bbls

    3.16bbls

    P1V1 = P4V4

    V4 = 5700 x 1 / 1800

    V4 = 3.16 bbls

    1.8 bbls

    5,000 ft

    7,500 ft

    7500 x .52 = 3900 psi

    10,000 ft

    5,700 psi

    7,000 psi

    5,700 psi

    Gm = 0.52 psi/ft

    1.84 bbl gain

    1.84 bbl gain

    3.16 bbl gain


    500 psi pressure as increasing the mud weight.

    1800 psi

    500 psi

    Volume to bleed off to keep BHP constant

    1800 psi

    500 psi

    0 ft

    P1V1 = P5V5

    V5 = 5700 x 1 / 500

    V5 = 11.4 bbls

    3.16 bbls

    11.4bbls

    2,500 ft

    3.16 bbls

    5,000 ft

    7,500 ft

    10000 x .52 = 5200 psi

    10,000 ft

    5,700 psi

    7,000 psi

    5,700 psi

    Gm = 0.52 psi/ft

    3.16 bbl gain

    3.16 bbl gain

    11.4 bbl gain


    WELL # 1 pressure as increasing the mud weight.

    HOLE SIZE

    HOLE DEPTH TVD/MD

    CASING 9-5/8” TVD/MD

    DRILL PIPE CAP.

    HEAVY WALL DRILL PIPE

    CAPACITY

    DRILL COLLARS 6-1/4”

    CAPACITY

    DRILLING FLUID DENSITY

    CAPACITY OPEN HOLE/COLLARS

    CAPACITY OPEN HOLE/DRILL PIPE-HWDP

    CAPACITY CASING/DRILL PIPE

    FRACTURE FLUID DENSITY

    SIDPP

    SICP

    PUMP DISPLACEMENT

    RRCP 30 SPM

    PIT GAIN

    8-1/2 INCH

    11536 FEET

    9875 FEET

    0.01741 BBL/FEET

    600 FEET

    0.00874 BBL/FEET

    880 FEET

    0.00492 BBL/FEET

    14.0 PPG

    0.03221 BBL/FEET

    0.04470 BBL/FEET

    0.04891 BBL/FEET

    16.9 PPG

    530 PSI

    700 PSI

    0.1019 BBL/STRK

    650 PSI

    10.0 BBL


    DRILLERS METHOD pressure as increasing the mud weight.

    1st CIRCULATION

    DP

    CSG

    0

    1489

    0

    MAASP

    SHUTTING

    IN

    WELL

    700

    530

    O

    C

    7889

    7189

    Ph= 8398 psi

    Pf= 8928 psi


    DRILLERS METHOD pressure as increasing the mud weight.

    1st CIRCULATION

    DP

    CSG

    30

    1489

    22

    REACHING

    ICP

    KEEP CONSTANT

    CASING PRESSURE

    WHILE BRINGING

    PUMPS UP

    PUMPS UP AND

    PRESSURE STABILISED

    KEEP CONSTANT

    DRILL PIPE PRESSURE

    MAASP

    700

    1180

    O

    C

    7889

    BHP= 8928 PSI

    Pf= 8928 psi


    DRILLERS METHOD pressure as increasing the mud weight.

    1st CIRCULATION

    DP

    CSG

    30

    GAS IN OPEN HOLE

    CONSTANT

    DRILL PIPE PRESSURE

    GAS EXPANDING

    CASING PRESSURE

    INCREASE

    SHOE PRESSURE

    INCREASE

    MAASP CONSTANT

    1489

    310

    MAASP

    740

    1180

    O

    C

    7929

    BHP= 8928 PSI

    Pf= 8928 psi


    DRILLERS METHOD pressure as increasing the mud weight.

    1st CIRCULATION

    DP

    CSG

    30

    GAS REACH SHOE

    CONSTANT

    DRILL PIPE PRESSURE

    GAS EXPANDING

    CASING PRESSURE

    INCREASE

    SHOE PRESSURE

    INCREASE TO MAX

    MAASP CONSTANT

    1489

    470

    MAASP

    775

    1180

    O

    C

    7964

    BHP= 8928 PSI

    Pf= 8928 psi


    DRILLERS METHOD pressure as increasing the mud weight.

    1st CIRCULATION

    DP

    CSG

    30

    GAS MOVES INSIDE

    CASING

    CONSTANT

    DRILL PIPE PRESSURE

    GAS EXPANDING

    CASING PRESSURE

    INCREASE

    SHOE PRESSURE

    DECREASE

    MAASP INCREASING

    1685

    620

    MAASP

    785

    1180

    O

    C

    7718

    BHP= 8928 PSI

    Pf= 8928 psi


    DRILLERS METHOD pressure as increasing the mud weight.

    1st CIRCULATION

    DP

    CSG

    30

    GAS MOVING INSIDE

    CASING

    CONSTANT

    DRILL PIPE PRESSURE

    GAS EXPANDING

    CASING PRESSURE

    INCREASE

    SHOE PRESSURE

    CONSTANT

    MAASP INCREASING

    2020

    2300

    MAASP

    1120

    1180

    O

    C

    7718

    BHP= 8928 PSI

    Pf= 8928 psi


    DRILLERS METHOD pressure as increasing the mud weight.

    1st CIRCULATION

    DP

    CSG

    30

    GAS REACH CHOKE

    CONSTANT

    DRILL PIPE PRESSURE

    GAS EXPANDING

    CASING PRESSURE

    INCREASE TO MAX

    SHOE PRESSURE

    CONSTANT

    MAASP

    INCREASE TO MAX

    2480

    4800

    MAASP

    1580

    1180

    O

    C

    7718

    BHP= 8928 PSI

    Pf= 8928 psi


    DRILLERS METHOD pressure as increasing the mud weight.

    1st CIRCULATION

    DP

    CSG

    30

    GAS OUT OF WELL

    CONSTANT

    DRILL PIPE PRESSURE

    CASING PRESSURE

    DECREASING TO SIDPP

    SHOE PRESSURE

    CONSTANT

    MAASP DECREASING

    TO ORIGINAL VALUE

    1489

    5400

    MAASP

    530

    1180

    O

    C

    7718

    BHP= 8928 PSI

    Pf= 8928 psi


    DRILLERS METHOD pressure as increasing the mud weight.

    2nd CIRCULATION

    DP

    CSG

    30

    START PUMPING

    KILL MUD 14.9 PPG

    CASING PRESSURE

    CONSTANT

    SHOE PRESSURE

    CONSTANT

    MAASP CONSTANT

    1489

    5400

    MAASP

    530

    1180

    O

    C

    7718

    BHP= 8928 PSI

    Pf= 8928 psi


    DRILLERS METHOD pressure as increasing the mud weight.

    2nd CIRCULATION

    DP

    CSG

    30

    KILL FLUID INSIDE

    DRILL PIPE

    CASING PRESSURE

    CONSTANT

    DRILL PIPE PRESSURE

    DECREASING

    SHOE PRESSURE

    CONSTANT

    MAASP CONSTANT

    1489

    6306

    MAASP

    530

    936

    O

    C

    7718

    BHP= 8928 PSI

    Pf= 8928 psi


    DRILLERS METHOD pressure as increasing the mud weight.

    2nd CIRCULATION

    DP

    CSG

    30

    KILL MUD REACH

    BIT

    CONSTANT CASING

    PRESSURE

    DRILL PIPE PRESSURE

    DECREASING TO FCP

    SHOE PRESSURE

    CONSTANT

    MAASP CONSTANT

    1489

    7212

    MAASP

    530

    692

    O

    C

    7718

    BHP= 8928 PSI

    Pf= 8928 psi


    DRILLERS METHOD pressure as increasing the mud weight.

    2nd CIRCULATION

    DP

    CSG

    30

    KILL MUD REACH

    SHOE

    DRILL PIPE PRESSURE

    CONSTANT

    CASING PRESSURE

    DECREASING

    SHOE PRESSURE

    DECREASING

    MAASP CONSTANT

    1489

    7832

    MAASP

    469

    692

    O

    C

    7657

    BHP= 8928 PSI

    Pf= 8928 psi


    DRILLERS METHOD pressure as increasing the mud weight.

    2nd CIRCULATION

    DP

    CSG

    30

    KILL MUD INSIDE

    CASING

    DRILL PIPE PRESSURE

    CONSTANT

    CASING PRESSURE

    DECREASING

    SHOE PRESSURE

    CONSTANT

    MAASP DECREASING

    1253

    10202

    MAASP

    233

    692

    O

    C

    7657

    BHP= 8928 PSI

    Pf= 8928 psi


    DRILLERS METHOD pressure as increasing the mud weight.

    2nd CIRCULATION

    DP

    CSG

    30

    KILL MUD AT

    SURFACE

    DRILL PIPE PRESSURE

    CONSTANT

    CASING PRESSURE

    DECREASING TO ZERO

    SHOE PRESSURE

    CONSTANT

    MAASP DECREASING

    TO NEW MAASP w/KMW

    1020

    12600

    MAASP

    0

    692

    O

    C

    7657

    BHP= 8928 PSI

    Pf= 8928 psi


    WELL # 1 pressure as increasing the mud weight.

    HOLE SIZE

    HOLE DEPTH TVD/MD

    CASING 9-5/8” TVD/MD

    DRILL PIPE CAP.

    HEAVY WALL DRILL PIPE

    CAPACITY

    DRILL COLLARS 6-1/4”

    CAPACITY

    DRILLING FLUID DENSITY

    CAPACITY OPEN HOLE/COLLARS

    CAPACITY OPEN HOLE/DRILL PIPE-HWDP

    CAPACITY CASING/DRILL PIPE

    FRACTURE FLUID DENSITY

    SIDPP

    SICP

    PUMP DISPLACEMENT

    RRCP 30 SPM

    PIT GAIN

    8-1/2 INCH

    11536 FEET

    9875 FEET

    0.01741 BBL/FEET

    600 FEET

    0.00874 BBL/FEET

    880 FEET

    0.00492 BBL/FEET

    14.0 PPG

    0.03221 BBL/FEET

    0.04470 BBL/FEET

    0.04891 BBL/FEET

    16.9 PPG

    530 PSI

    700 PSI

    0.1019 BBL/STRK

    650 PSI

    10.0 BBL


    WAIT & WEIGHT METHOD pressure as increasing the mud weight.

    DP

    CSG

    0

    1489

    0

    MAASP

    SHUTTING

    IN

    WELL

    MIXING KILL MUD

    14.9 PPG

    700

    530

    O

    C

    7889

    7189

    Ph= 8398 psi

    Pf= 8928 psi


    WAIT & WEIGHT METHOD pressure as increasing the mud weight.

    DP

    CSG

    30

    REACHING

    ICP

    KEEP CONSTANT

    CASING PRESSURE

    WHILE BRINGING

    PUMPS UP

    PUMPS UP AND

    PRESSURE STABILISED

    KEEP DRILL PIPE

    PRESSURE ON

    SCHEDULE

    1489

    22

    MAASP

    700

    1180

    O

    C

    7889

    BHP= 8928 PSI

    Pf= 8928 psi


    WAIT & WEIGHT METHOD pressure as increasing the mud weight.

    DP

    CSG

    30

    GAS IN OPEN HOLE

    DRILL PIPE PRESSURE

    DECREASING

    CASING PRESSURE

    INCREASING

    GAS EXPANDING

    SHOE PRESSURE

    INCREASING

    MAASP CONSTANT

    1489

    310

    MAASP

    740

    1097

    O

    C

    7929

    BHP= 8928 PSI

    Pf= 8928 psi


    WAIT & WEIGHT METHOD pressure as increasing the mud weight.

    DP

    CSG

    30

    GAS REACH SHOE

    DRILL PIPE PRESSURE

    DECREASING

    CASING PRESSURE

    INCREASING

    GAS EXPANDING

    SHOE PRESSURE

    INCREASE TO MAX

    MAASP CONSTANT

    1489

    470

    MAASP

    775

    1053

    O

    C

    7964

    BHP= 8928 PSI

    Pf= 8928 psi


    WAIT & WEIGHT METHOD pressure as increasing the mud weight.

    DP

    CSG

    30

    GAS MOVES INSIDE

    CASING

    DRILL PIPE PRESSURE

    DECREASING

    CASING PRESSURE

    INCREASING

    GAS EXPANDING

    SHOE PRESSURE

    DECREASING

    MAASP INCREASING

    1685

    620

    MAASP

    785

    1013

    O

    C

    7718

    BHP= 8928 PSI

    Pf= 8928 psi


    WAIT & WEIGHT METHOD pressure as increasing the mud weight.

    DP

    CSG

    30

    KILL MUD AT BIT

    GAS INSIDE CASING

    DRILL PIPE PRESSURE

    DECREASE TO FCP

    CASING PRESSURE

    INCREASING

    GAS EXPANDING

    SHOE PRESSURE

    CONSTANT

    MAASP INCREASING

    1950

    1812

    MAASP

    1050

    692

    O

    C

    7718

    BHP= 8928 PSI

    Pf= 8928 psi


    WAIT & WEIGHT METHOD pressure as increasing the mud weight.

    DP

    CSG

    30

    KILL MUD AT SHOE

    GAS INSIDE CASING

    DRILL PIPE PRESSURE

    CONSTANT

    CASING PRESSURE

    INCREASING

    GAS EXPANDING

    SHOE PRESSURE

    DECREASING

    MAASP INCREASING

    1980

    2432

    MAASP

    1080

    692

    O

    C

    7641

    BHP= 8928 PSI

    Pf= 8928 psi


    WAIT & WEIGHT METHOD pressure as increasing the mud weight.

    DP

    CSG

    30

    KILL MUD INSIDE

    CASING

    GAS REACH CHOKE

    DRILL PIPE PRESSURE

    CONSTANT

    CASING PRESSURE

    INCREASING

    GAS EXPANDING

    SHOE PRESSURE

    CONSTANT

    MAASP INCREASING

    2178

    4800

    MAASP

    1278

    692

    O

    C

    7641

    BHP= 8928 PSI

    Pf= 8928 psi


    WAIT & WEIGHT METHOD pressure as increasing the mud weight.

    DP

    CSG

    30

    KILL MUD INSIDE

    CASING

    GAS OUT OF WELL

    DRILL PIPE PRESSURE

    CONSTANT

    CASING PRESSURE

    DECREASING

    SHOE PRESSURE

    CONSTANT

    MAASP DECREASING

    1204

    5360

    MAASP

    180

    692

    O

    C

    7641

    BHP= 8928 PSI

    Pf= 8928 psi


    WAIT & WEIGHT METHOD pressure as increasing the mud weight.

    DP

    CSG

    30

    KILL MUD AT

    SURFACE

    DRILL PIPE PRESSURE

    CONSTANT

    CASING PRESSURE

    DECREASING TO ZERO

    SHOE PRESSURE

    CONSTANT

    MAASP DECREASING

    TO NEW MMASP w/KMW

    1027

    7200

    MAASP

    0

    692

    O

    C

    7641

    BHP= 8928 PSI

    Pf= 8928 psi


    WELL # 1 pressure as increasing the mud weight.

    HOLE SIZE

    HOLE DEPTH TVD/MD

    CASING 9-5/8” TVD/MD

    DRILL PIPE CAP.

    HEAVY WALL DRILL PIPE

    CAPACITY

    DRILL COLLARS 6-1/4”

    CAPACITY

    DRILLING FLUID DENSITY

    CAPACITY OPEN HOLE/COLLARS

    CAPACITY OPEN HOLE/DRILL PIPE-HWDP

    CAPACITY CASING/DRILL PIPE

    FRACTURE FLUID DENSITY

    SIDPP

    SICP

    PUMP DISPLACEMENT

    RRCP 30 SPM

    PIT GAIN

    8-1/2 INCH

    11536 FEET

    9875 FEET

    0.01741 BBL/FEET

    600 FEET

    0.00874 BBL/FEET

    880 FEET

    0.00492 BBL/FEET

    14.0 PPG

    0.03221 BBL/FEET

    0.04470 BBL/FEET

    0.04891 BBL/FEET

    16.9 PPG

    530 PSI

    700 PSI

    0.1019 BBL/STRK

    650 PSI

    10.0 BBL


    VOLUMETRIC METHOD pressure as increasing the mud weight.

    MIGRATION DISTANCE

    GMD = -------------------------

    P2 - P1

    MUD GRADIENT

    MIGRATION RATE/HRS

    GMR = -------------------------

    GMD x 60

    T2 - T1


    VOLUMETRIC METHOD pressure as increasing the mud weight.

    KEY POINT:

    EVERY BARREL OF MUD IN THE WELLBORE REPRESENT

    A CERTAIN AMOUNT OF HYDROSTATIC PRESSURE

    Ph

    Ph


    VOLUMETRIC METHOD pressure as increasing the mud weight.

    CHOKE PRESSURE

    SICP + SAFETY FACTOR + WORKING RANGE

    PRESSURE/BARREL

    PSI/BBL = ----------------------------

    14.88 = ----------------------------

    WORKING RANGE

    50 PSI

    VOLUME TO BLEED =--------------------

    3.36 BBL =-----------------------------

    MUD GRADIENT

    W.R.

    CAPACITY

    PSI/BBL

    14 x 0.052

    50

    0.04891

    14.88


    300 psi pressure as increasing the mud weight.

    PA

    P2 - P1

    GMD = --------------------------

    GMR = --------------------------

    Where: GMD = Gas migration distance

    MWG = Mud gradient

    P1 = Surface pressure at time T1

    P2 = Surface pressure at time T2

    GMR = Gas migration rate ( feet per hour)

    T1 = Time 1 (hour)

    T2 = Time 2 (hour)

    MWG

    GMD

    12.5 ppg

    T2 - T1

    10000 ft

    GAS

    6500 psi

    VOLUMETRIC METHOD


    300 psi pressure as increasing the mud weight.

    PA

    P2 - P1

    GMD = --------------------------

    GMR = --------------------------

    Where: GMD = Gas migration distance

    MWG = Mud gradient

    P1 = Surface pressure at time T1

    P2 = Surface pressure at time T2

    GMR = Gas migration rate ( feet per hour)

    T1 = Time 1 (hour)

    T2 = Time 2 (hour)

    MWG

    GMD

    12.5 ppg

    T2 - T1

    10000 ft

    GAS

    6500 psi

    VOLUMETRIC METHOD


    VOLUMETRIC METHOD pressure as increasing the mud weight.


    BOP pressure as increasing the mud weight.

    Vm

    HALLIBURTON

    PA

    P3

    Vm

    6

    KILL LINE

    P3

    Vm

    5

    P3

    Vm

    3

    4

    Pa

    P3

    GAS

    6

    2

    P1

    1

    5

    GAS

    S

    I

    C

    P

    4

    GAS

    BLEED OFF

    LUBRICATE

    3

    GAS

    P3

    2

    GAS

    1

    GAS

    BHP

    P1

    VOLUMETRIC METHOD


    PRESSURE pressure as increasing the mud weight.

    Gas bubble pressure

    Bottom hole pressure

    Annular pressure

    Drill pipe pressure

    BLEED OFF

    LUBRICATE

    TIME

    VOLUMETRIC METHOD


    Bull heading
    Bull heading pressure as increasing the mud weight.

    • Involves forcing formation fluids back into the formation using surface hydraulics

    • Usually considered if:

      1 Formation fluid cannot be safely handled on surface (eg with H2S)

      2 If anticipated formation pressures exceed what can be safely handled

    • Method usually employed as a last resort


    Tertiary well control methods
    Tertiary well control Methods pressure as increasing the mud weight.

    • Cement Plug

    • Barite plug

    • Gunk plug


    Shallow Gas pressure as increasing the mud weight.

    • Evaluation & Planning

    • Drill a pilot hole

    • Heavy mud in ready(1-2 ppg higher)

    • Controlled ROP

    • Use of Viscous pills instead of weighted pills

    • High circulation rates

    • Float in string


    Diverting shallow gas
    Diverting Shallow Gas pressure as increasing the mud weight.

    INTERLOCKED

    • Open vent line

    • Close Diverter

    • Switch suctions to heavy mud

    • Increase pump speed to maximum

    • Circulate heavy mud round

    • Flow check

    • If still positive continue pumping.( if mud finished continue with water)


    Well Control pressure as increasing the mud weight.

    Complications


    Well Control Complications pressure as increasing the mud weight.


    Well control complications
    WELL CONTROL COMPLICATIONS pressure as increasing the mud weight.


    Lost circulation
    Lost Circulation pressure as increasing the mud weight.

    • Formation breakdown

    • Fractures and Fissures

    • Bad cement


    Loss circulation
    Loss Circulation pressure as increasing the mud weight.

    Categories:

    • Seepage losses (<2bbl/Hr)

    • Partial losses (5-50 bbl/Hr)

    • Severe losses (>50bbl/Hr)

    • Complete losses (unable to maintain fluid level at surface with desired mud weight)


    Hydrates pressure as increasing the mud weight.

    Hydrates


    Hydrates pressure as increasing the mud weight.

    • What are hydrates?

    • Hydrates are a solid mixture of water and natural gas (commonly methane).

    • Once formed, hydrates are similar to dirty ice .


    Hydrates pressure as increasing the mud weight.

    • Why are they important?

    • Hydrates can cause severe problems by forming a plug in Well Control equipment, and may completely blocking flow path.

    • One cubic foot of hydrate can contain as much as 170 cubic feet of gas.

    • Hydrates could also form on the outside of the BOP stack in deepwater.


    Hydrates pressure as increasing the mud weight.

    • Where do they form?

    • In deepwater Drilling

    • High Wellhead Pressure

    • Low Wellhead temperature


    Hydrates pressure as increasing the mud weight.

    • How to prevent hydrates?

    • Good primary well control = no gas in well bore

    • Composition of Drilling Fluid by using OBM or Chloride (Salt) in WBM.

    • Well bore temperature as high as possible

    • Select proper Mud Weight to minimize wellhead pressure.

    • injecting methanol or glycol at a rate of 0.5 - 1 gal per minutes on the upstream side of a choke


    Hydrates pressure as increasing the mud weight.


    Wet and dry tripping

    Wet And Dry Tripping pressure as increasing the mud weight.


    Tripping Dry pressure as increasing the mud weight.

    When a length of pipe is pulled from the hole, the mud level will fall.


    Tripping Dry pressure as increasing the mud weight.

    The volume of fall is equal to the volume of steel pulled from the hole.

    The trip tank is then used to fill up the hole.

    If 1 barrel of steel is removed from the hole, then using the trip tank, we have to add 1 barrel of mud.


    Tripping Dry pressure as increasing the mud weight.

    1- Calculate the volume of steel pulled:

    Length x Metal Displacement

    Example:

    DP Metal Disp = 0.00764 bbls/ft

    Length Pulled 93 feet

    Volume Of Steel Pulled:

    93 x 0.00764 = 0.711 bbls


    Tripping Dry pressure as increasing the mud weight.

    2- Fill up the hole:

    You must pump 0.711 barrel of mud from the trip tank.

    You must investigate ( flow check) if more mud or less mud is needed.


    Tripping Dry pressure as increasing the mud weight.

    3- NO FILL UP:

    If you fail to fill up the hole, the mud level will drop by the volume of steel pulled.

    It will drop inside the pipe and in the annulus.


    Tripping Dry pressure as increasing the mud weight.

    3- NO FILL UP:

    Example:

    Volume Of Steel Pulled:

    93 x 0.00764 = 0.711 bbls

    DP Capacity: 0.01776 bbl/ft

    Annular Capacity: 0.0504 bbl/ft

    The mud will drop inside the pipe and the annular:

    0.01776 + 0.0504 = 0.06816 bbl/ft


    Tripping Dry pressure as increasing the mud weight.

    3- NO FILL UP:

    Example Cont’d:

    The volume of drop is 0.711 bbls and will drop in a volume of

    0.06816 bbl / ft,

    then the length of drop will be:

    0.711 / 0.06816 = 10.4 feet.

    If 93 feet (1 stand) are pulled with no fill up, the mud level will drop by 10.4 feet.


    Tripping Wet pressure as increasing the mud weight.

    When a length of pipe is pulled from the hole, the mud level will fall.


    Tripping Wet pressure as increasing the mud weight.

    The volume of fall is equal to the volume of steel pulled from the hole plus the volume of mud inside this pipe.

    The trip tank is then used to fill up the hole.

    If 3 barrels of steel and mud are removed from the hole, then using the trip tank, we have to add 3 barrels of mud.


    Tripping Wet pressure as increasing the mud weight.

    1- Calculate the volume of steel pulled:

    Length x Metal Displacement

    Example:

    DP Metal Disp = 0.00764 bbls/ft

    Length Pulled 93 feet

    Volume Of Steel Pulled:

    93 x 0.00764 = 0.711 bbls


    Tripping Wet pressure as increasing the mud weight.

    2- Calculate the volume of mud pulled:

    Length x DP Capacity

    Example:

    DP Capacity = 0.01776 bbls/ft

    Length Pulled 93 feet

    Volume Of Mud Pulled:

    93 x 0.01776 = 1.65 bbls


    Tripping Wet pressure as increasing the mud weight.

    3- Calculate the total volume of steel and mud pulled:

    1.65 + 0.711 = 2.36 barrels


    Tripping Wet pressure as increasing the mud weight.

    4- Fill up the hole:

    You must pump 2.36 barrels of mud from the trip tank.

    You must investigate ( flow check) if more mud or less mud is needed.


    Tripping Wet pressure as increasing the mud weight.

    5- NO FILL UP:

    If you fail to fill up the hole, the mud level will drop by the volume of steel and mud pulled.

    It will drop inside the annulus.


    Tripping Wet pressure as increasing the mud weight.

    5- NO FILL UP:

    Example:

    Volume Of Steel and Mud Pulled:

    93 x (0.00764+0.01776) = 2.36 bbls

    Annular Capacity: 0.0504 bbl/ft

    The mud will drop inside the annular by:

    2.36 / 0.0504 = 46.9 feet


    Pumping a Slug pressure as increasing the mud weight.

    It is usefull to pump a slug before tripping.

    The slug weight being heavier than the mud, a length of pipe will be empty.

    The HP is not reduced because the heavier mud will compensate for the empty pipe.


    Pumping a Slug pressure as increasing the mud weight.

    The total HP is the same on both sides of the pipe.

    HP kmw

    HP mud

    HP mud


    Pumping a Slug pressure as increasing the mud weight.

    Example:

    If 20 bbls of 12 ppg slug are pumped in a 10,000 ft hole containing 10 ppg mud, what will be the height of empty pipe?

    DP capacity = 0.01776 bbl/ft

    1- Calculate the height of the slug:

    20 / 0.01776 = 1126 ft


    Pumping a Slug pressure as increasing the mud weight.

    2- Calculate the HP of the slug:

    1126 x 12 x 0.052 = 702.6 psi

    702.6 psi


    Pumping a Slug pressure as increasing the mud weight.

    2- Calculate the HP of the mud in the annulus:

    10,000 x 10 x 0.052 = 5,200 psi

    702.6 psi

    5,200 psi


    Pumping a Slug pressure as increasing the mud weight.

    3- The total hydrostatic beeing the same on both sides, calculate the HP of the mud below the slug:

    5,200 - 702.6 = 4497.4 psi

    702.6 psi

    5,200 psi

    4497.4 psi


    Pumping a Slug pressure as increasing the mud weight.

    4- Calculate the height of mud needed to give 4497.4 psi as a HP:

    TVD = 4497.4 / ( 10 x 0.052 ) = 8648.8 feet

    1,126 ft

    10,000 ft

    8648.8 ft


    Pumping a Slug pressure as increasing the mud weight.

    4- Calculate the height of empty pipe

    10,000 - 8648.8 - 1,126 = 225.2 ft

    225.2 ft

    1,126 ft

    10,000 ft

    8648.8 ft


    ad