Well Intervention Pressure Control Instructor Information Pack

 

Intervention n Pressure Control Syllabi Well Interventio Instructor Information

 

Contents 1

Overview

2 

Well Interven tion Pressure Control - English API Formula Sheet

3 

Well Interven tion Pressure Control – English BL 0.0981 Formula Sheet

4 

Well Intervention Pressure Control - English BL 10.2 Formula Sheet

5

Well Intervention Pressure Pressure Control - English SI Formula Sheet

6 

Well Interven tion Pressure Control - English KGM Formula Sheet

7

Well Intervention Pressure Control Barrier Philosophy

 

 

Overview From 1 July 2019, we will assess candidates in line with the new Well Intervention Pressure Control (WIPC) syllabi. The below information will help instructors understand the new syllabi and assessment.

The new syllabi We updated the syllabi using guidance from our stakeholders, candidates and the WIPC Taskforce. It aims to meet the principles outlined in IOGP Report 47 476 6 ‘Recommendations for enhancements to well control training, examination and certification (August  20 16 )’ . The new syllabi includes: -

an improved structure to avoid duplicate topics detailed learning outcomes to aid instructors role specific learning outcomes an improved focus on the common principles of PCE.

WIPC assessments assessments f rom 1 July A technical-review team approved approved all questions for the new assessments. We have removed any existing questions that do not meet the new syllabi learning outcomes. Both level 3 and level 4 assessments now have a set of questions about a well kill scenario. Candidates must analyse a kill graph and answer five following questions. In line with the 2017 IWCF Drilling Drilling Syllabi update, all WIPC questions are now equally weighted at one point per question.

Formula sheet Please find the attached updated WIPC formula sheet which contains all formulas for the new syllabi.

Barrier document We have also updated the ‘IWCF Barrier Philosophy’. This document incorporates the barrier principles of ISO, NORSOK and API and is a basis for all barrier-related barrier-related assessment questions.

Overview

1

 

 

Well Intervention Pressure Control  Control  – – English API API Formula Sheet

 Abbr  Ab br evi ati on s  Abbr  Ab br evi ati on

Term

bbl

Barrels (US)

bbl/ft

Barrels (US) per foot

bbl/min

Barrels (US) per minute

ft

Feet

ID MD

Inside diameter Measured depth

OD

Outside diameter

P

Pressure

ppg

Pounds per gallon

psi

Pounds per square inch

psi/ft

Pounds per square inch per foot

SICHP

Shut-in casing head pressure

SITHP

Shut-in tubing head pressure

TVD

True vertical depth

V

Volume Constant factors

Constant factor pressure Constant factor capacity

0.052 1029.4

Formulas 1. Pressure gradient (psi/ft)

Fluid density (ppg) x 0.052  2. Fluid density (ppg)

Hydrostatic Pressure (psi) ÷ TVD (ft) ÷ 0.052 or Hydrostatic pressure (psi) TVD (ft) x 0.052

 

3. Hydrostatic pr essure (psi)

Fluid Density (ppg) x 0.052 x TVD (ft) or   Pressure Gradient (psi/ft) x TVD (ft) 4. Formation Pressure (psi)

Hydrostatic Column Pressure (psi) + SITHP (psi)

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Well Intervention Pressure Control  Control  – – English API API Formula Sheet

5. Kill Weight Gradient (psi/ft)

(Well fluid gradient x TVD to point of circulation) + SITHP (psi) + *Overbalance (psi)

 

TVD to point of circulation *overbalance is variable and will be stated  6. Time to pump (minut (minut es)

Capacity (bbl/ft) x MD (ft) Pump rate (bbl/min)

 

7. Tubing Capacity Capacity (bbl/ft) 

Tubing ID2 (inches) 1029.4

 

8. Annular Capacity Capacity (bbl/ft) 2

Casing ID2 (inches) - Tubing ID  (inches)

 

1029.4 9. Volum e (bbl) Capacity (bbl/ft) x MD (ft) 10. Time to displace (minutes) Volume (bbl) ÷ Pump Output (bbl/min)  11. Area of a circle (inches 2) 0.785 x diameter (inches)2  12. Force

 Area (inches2) x applied pressure (psi) = lbs force 13 13.. New New circ ulating pressure (psi) (psi)   Pump pressure (psi) x [new [ new pump rate (bbl/min) ÷ old pump rate (bbl/min)]2 

14. Basic gas Laws

P1   ×  V1  = P2

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P2  =

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V2  =

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P1   ×  V1 P2

 

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Well Intervention Pressure Control – English BL 0.0981 Formula Sheet

 Abbr  Ab br evi ati on ons s  Ab br evi ati on  Abbr bar bar/m ID kg

Term Bar (pressure) Bar per metre Inside diameter Kilogram

kg/l l l/m l/min m MD mm OD P SICHP SITHP TVD V

Kilogram per litre Litres Litres per metre Litres per minute Metres Measured depth Millimetres Outside diameter Pressure Shut-in casing head pressure Shut-in tubing head pressure True vertical depth Volume

Constant factors Constant factor pressure 0.0981 Constant factor capacity (using mm) 0.0007854 Constant factor capacity (using inches) 1.9735 Formulas 1. Pressur e gradi ent (bar/m) Fluid density (kg/l) x 0.0981 2. Fluid density (kg/l) Hydrostatic pressure (bar) ÷ TVD (m) ÷ 0.0981   or Hydrostatic pressure (bar) TVD (m) x 0.0981

 

3. Hydrostatic pressure pressure (bar) (bar) Fluid Density (kg/l) x 0.0981 x TVD(m) or   pressure gradient (bar/m) x TVD (m) 4. Formati on Pressur e (bar) Hydrostatic column pressure (bar) + SITHP (bar)

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Well Intervention Pressure Control – English BL 0.0981 Formula Sheet

5. Kil l Weight Gradient (bar/m) (Well fluid gradient x TVD to point of circulation) + SITHP (bar) + *overbalance *overbalance (bar)  

TVD to point of circulation *overbalance is variable and will be stated 6. Time to pump (minut (minut es) Capacity (l/m) x MD (m) Pump rate (l/min)

 

7. Tubin g Capacit Capacit y (l/m) Tubing ID2 (mm) x 0.0007854

8.

or    or 

tubing ID2 (inches) ÷ 1.9735

Annu lar Capacit Capacit y (l/m) Casing ID² (inches) - Tubing OD² (inches)   1.9735 or   Casing ID2(mm) – tubing OD2 (mm) x 0.0007854

9. Volum e (l) (l)   Capacity (l/m) x MD(m) 10. Time to displace (minutes) Volume (l) ÷ pump output (l/min)  11 11.. Area of a cir cle (cm 2) 0.785 x diameter (cm)2  12. Force 1.02 x area (cm2) x applied pressure (bar) = kg force 13. New cir cul ating pressur e (bar)  (bar)  Pump pressure (bar) x [new pump rate (l/min) ÷ old pump rate (l/min)] 2  14. Basic gas laws

P1   ×  V1  = P2

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 V2 

P2  =

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P1   ×  V1 V2

 

V2  =

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P1   ×  V1 P2

 

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Well Intervention Pressure Control – English BL 10.2 Formula Sheet

 Abbr  Ab br evi ati on ons s  Ab br evi ati on  Abbr bar bar/m ID kg

Term Bar (pressure) Bar per metre Inside diameter Kilogram

kg/l l l/m l/min m MD mm OD P SICHP SITHP TVD V

Kilogram per litre Litres Litres per metre Litres per minute Metres Measured depth Millimetres Outside diameter Pressure Shut-in casing head pressure Shut-in tubing head pressure True vertical depth Volume Constant factors

Constant factor pressure Constant factor capacity (using mm) Constant factor capacity (using inches)

10.2  0.0007854  1.9735 

Formulas 1. Pressur e gradi ent (bar/m) Fluid density (kg/l) ÷ 10.2 2. Fluid density (kg/l) Hydrostatic pressure (bar) x 10.2 TVD (m) 3. Hydrostatic pressure pressure (bar) (bar)

Fluid density (kg/l) x TVD (m) or  

10.2

 

pressure gradient (bar/m) x TVD (m) 4. Formati on Pressur e (bar) Hydrostatic column pressure (bar) + SITHP (bar) 5. Kil l Weigh Weigh t Gradient (bar/m)

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Well Intervention Pressure Control – English BL 10.2 Formula Sheet

(Well fluid gradient x TVD to point of circulation) + SITHP (bar) + *overbalance *overbalance (bar) TVD to point of circulation

 

*overbalance is variable and will be stated 6. Time to pump (minut (minut es) Capacity (l/m) x MD (m)

 

Pump rate (l/min) 7. Tubin g Capacit Capacit y (l/m) Tubing ID2 (mm) x 0.0007854

8.

or    or 

tubing ID2 (inches) ÷ 1.9735

Annu lar Capacit Capacit y (l/m) Casing ID² (inches) - Tubing OD² (inches)   1.9735 or   Casing ID2(mm) – tubing OD2 (mm) x 0.0007854

9. Volum e (l) (l)   Capacity (l/m) x MD(m) 10. Time to displace (minutes) Volume (l) ÷ pump output (l/min)  11 11.. Area of a cir cle (cm 2) 0.785 x diameter (cm)2  12. Force 1.02 x area (cm2) x applied pressure (bar) = kg force 13. New cir cul ating pressur e (bar)  (bar)  Pump pressure (bar) x [new pump rate (l/min) ÷ old pump rate (l/min)] 2  14. Basic gas laws

P1   ×  V1  = P2

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 V2 

P2  =

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P1   ×  V1 V2

 

V2  =

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P1   ×  V1 P2

 

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Well Intervention Pressure Control  Control  – – English SI Formula Formula Sheet

 Abbr  Ab br evi ati on ons s  Ab br evi ati on  Abbr cm ID kg kPa

Term Centimetres Inside diameter Kilogram Kilopascal

kPa/m m m3 m3/m m3/min MD mm kg/ m3 OD P SICHP SITHP TVD

Kilopascal per metre Metres Cubic metre Cubic metres per metre Cubic metres per minute Measured depth Millimetres Kilogram per cubic metre Outside diameter Pressure Shut-in casing head pressure Shut-in tubing head pressure True vertical depth

V

Volume

Constant factors Constant factor pressure 0.00981 Constant factor capacity (using mm) 0.0000007854 0.000000785 4 Formulas 1. Pressur e gradi ent (kPa/m) (kPa/m) Fluid density (kg/mᵌ) x 0.00981  0.00981  2. Fluid density (kg/m3) Hydrostatic pressure (kPa) ÷ TVD(m) ÷ 0.00981  or Hydrostatic pressure (kPa) TVD(m) x 0.00981

 

3. Hydros tati c press ure (kPa) Fluid Density (kg/m3) x 0.00981 x TVD (m) or   pressure gradient gradient (kPa/m) x TVD (m) 4. Formati on Pressur e (kPa) Hydrostatic column pressure (kPa) + SITHP (kPa)

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Well Intervention Pressure Control  Control  – – English SI Formula Formula Sheet

5. Kil l Weigh Weigh t Gradient (kPa/m) (kPa/m) (Well fluid gradient x TVD to point of circulation) + SITHP (kPa) + *overbalance (kPa)  

TVD to point of circulation *overbalance is variable and will be stated 6. Time to pump (minut (minut es) Capacity (mᵌ/m) x MD (m) Pump rate (mᵌ/min)

 

7. Tubin g Capacit Capacit y (m 3/m) Tubing ID2 (mm) x 0 0..0000007854

or    or 

tubing ID2 (inches) ÷ 1.9735

8. Annu lar Capacit Capacit y (m 3/m)   Casing ID² (inches) – Tubing OD² (inches)   1.9735 or    or    Casing ID2(mm) – tubing OD2 (mm) x 0.0000007854

9. Volum e (m 3)  Capacity  (mᵌ/m) x MD (m) 10. Time to displace (minutes) Volume (mᵌ) ÷ pump output (mᵌ/min)  11. Area of a ci rcl e (cm2) 0.785 x diameter (cm)2  12. Force  Area (cm2) x (applied pressure (kPa) ÷ 98.0665) = kg force 13. New New circ ulatin g press ure (kPa) (kPa)   Pump pressure (kPa) x [new pump rate (mᵌ/min) ÷ old pump rate (mᵌ/min)]2  14. Basic gas laws

P1   ×  V1  = P2

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 V2 

P2  =

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P1   ×  V1 V2

 

V2  =

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P1   ×  V1 P2

 

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Well Intervention Pressure Control – English KGM Formula Sheet

 Abbr  Ab br evi ati on s

cm  ID kg kg/cm2 

Centimetres  Inside diameter kilogram Kilogram per centimetre squared

kg/l kg-cm/m l  l/m  l/min  m  MD mm  OD  SICHP SITHP TVD V

Kilogram per litre Kilogram per centimetre squared per metre Litres  Litres per metre Litres per minute  Meters  Measured depth  Millimetres  Outside diameter   Shut-in casing head pressure  Shut-in tubing head pressure  True vertical depth  Volume

Constant factors Constant Constant factor pressure 0.0981 Constant factor capacity (using mm) 0.0007854 Constant factor capacity (using inches) 1.9735 Formulas 1. Pressur e gradi ent (kg-cm 2/m) Fluid density(kg/l) x 0.0981 2. Fluid density (kg/l) 2

Hydrostatic pressure  pressure (kg/cm ) ÷ TVD(m) ÷ 0.0981

 

or Hydrostatic pressure (kg/cm²) TVD(m) x 0.0981

 

3. Hydrostatic pressure (kg/cm 2) Fluid Density (kg/l) x 0.0981 x TVD(m) or   pressure gradient (kg/cm2) x TVD(m) 4. Formation Pressure Pressure (kg/cm2) Hydrostatic column pressure (kg/cm2) + SITHP (kg/cm2)

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Well Intervention Pressure Control – English KGM Formula Sheet

5. Kill Weight Weight Gradient Gradient (kg-cm2/m) (Well fluid gradient x TVD to point of circulation) + SITHP (kg/cm²) + *overbalance *overbalance (kg/cm²)  

TVD to point of circulation *overbalance is variable and will be stated 6. Time to pump (minut (minut es) Capacity (l/m) x MD (m) Pump rate (l/min)

 

7. Tubin g Capacit Capacit y (l/m) Tubing ID2 (mm) x 0.0007854 8.

or    or 

tubing ID2 (inches) ÷ 1.9735

Annu lar Capacit Capacit y (l/m) Casing ID² (inches) - tubing OD² (inches)   1.9735 or   Casing ID2(mm) – tubing OD2 (mm) x 0.0007854

9. Volum e (l) (l)   Capacity (l/m) x MD (m) 10. Time to displace (minutes) Volume (l) ÷ pump output (l/min)   11. Area of a ci rcl e (cm2) 0.785 x diameter (cm)2  12. Force  Area (cm2) x applied pressure (kg/cm²) = kg force 13 13.. New New circ ulating pressure (kg/cm²) (kg/cm²)  Pump pressure (kg/cm²) x [new pump rate (l/min) ÷ old pump rate (l/min)] 2  14. Basic gas laws

P1   ×  V1  = P2

March 2019

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 V2 

P2  =

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P1   ×  V1 V2

 

V2  =

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P1   ×  V1 P2

 

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Well Control Barrier Philosophy

Well Control Barrier Philosophy Introduction The well control barrier philosophy outlined in this document is common across the IWCF syllabi for Drilling Well Control (DWC) and for Well W ell Intervention Pressure Control (WIPC) programmes. This well control barrier philosophy aims to meet the t he recommendations recommendations from tthe he International  Association of of Oil and Gas Producers Producers (IOGP) in report number number 476 issued in in August 2016. IWCF will incorporate the barrier principles of ISO, NORSOK and API as applied during different phases of the well life cycle. IWCF will use the relevant barrier terms and definitions included in the following standards:   ISO 16530-1   NORSOK D-010. •

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Local legislation, company standards and policy may differ. These differences must be addressed for each operation. Well We ll B arrier Termin Termin ology IWCF uses the terms ‘well barrier elements’ and ‘well barrier envelopes. These can be ‘primary’ or ‘secondary’. IWCF will not create new terms or definitions. While the reference sources outlined above have slightly different wording in their definitions, they are similar in principle. The terminology that is reflected in the syllabi and in the assessments is outlined below:  A "well barrier barrier element" is a physical physical element element that, when combined combined with other other well barrier barrier elements will prevent flow.   A primary primary barrier barrier is the first well barrier that that prevents prevents flow from a source.   A secondary secondary barrier barrier is the second second well well barrier barrier that prevents flow from a source. •

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 A "well barrier barrier envelope" is is made up of well well barrier elements elements that together prevent prevent flow. Minimum Requirements Requirements   There must always be two independent and tested well barriers (primary and secondary) to prevent flow. Both must be risk assessed, verified, approved and monitored during any operation on the well. Well barriers must be tested in line with the well owner’s performance standards and where applicable legislative requirements.  Any deviatio deviation n must follow a Management Management of Change Change (MOC) process, process, be specified and and documented documented including:   Mitigation Mitigat ion actions and responsibilit responsibilities ies must be in place and understood by all personnel.   A note of approval from senior person of the well owner management team who is accountable for the integrity of the well.

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Well Control Barrier Philosophy

Verification To verify a well barrier element, it must be installed where it is it intended to be used and must be function and integrity tested when installed.  A mechanically mechanically activated well well barrier element element must be able to contain contain well bore fluids by their own control system regardless of power failure. Integrity testing Integrity  testingof a flow. mechanical element integrity is done by pressure against the barrier in the direction Where well this barrier is not possible, canapplying be confirmed by decreasing pressure on the downstream side of the t he barrier (inflow testing/negative testing). testing).   If this cannot be achieved, other methods can be used if there is a formally endorsed risk assessment. For example: -  pressure testing, testing, not not in the direction direction of of flow from the well well -  verification of location location (for example, example, tagging of cement) cement) For a shear/seal device to qualify as a mechanical well barrier element, it must be able to first shear tubulars and then seal the well bore. To qualify a hydrostatic well barrier, the fluid level and properties must be monitored and maintained.   maintained. Operating Princi ples Operating ples    At all times, personnel personnel working on on the well should should understand: understand:            

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How to install and verify the well barrier elements. The acceptance acceptance criteria criteria for the correct positioning positioning and testing testing of the well well barrier barrier elements. elements. Which elements are primary and secondary barriers during any specific work on the well. The consequences of of well barriers changing during the operation. The consequence of well barrier failure The immediate actions they must take take ifif a well barrier fails.

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