Drilling Levels 3 and 4 Syllabus

International Well Control Forum

IWCF

Drilling Well Control Practical Assessment & Written Test Syllabus Levels 3 and 4 Surface & Subsea BOP Stack Standards and Performance Criteria Syllabus Structure This syllabus is divided into two sections; 1. Practical Assessment. 2. Written Testing. Section.1

Practical Assessment Assessment Syllabus

Not included in review document.

Section.2

Written Test Syllabus

The written test syllabus is divided into 2 sections; •

•

Principles and Procedures Equipment

Subsea requirements are prefixed by SS.

Surface Principles & Procedures Overview. Introduction to Well Control. Barrier Concept. Risk Management. Causes of kicks. Kill Warning Signs and Indicators. Circulating Systems. Fracture Pressure and Maximum Surface pressure. Influx Characteristics and Behaviour. Shut In Procedures. Well Control Methods. Well Control during Casing and Cementing Operations. Well Control Management. Contingency Planning.

A. B. C. D. E. F. G. H.

SSA. SSB. SSC. SSD. SSE. SSK. SSL. SSM.

I.

SSI.

J. K. L.

SSJ. SSK. SSL.

M. N.

SSM. SSN.

Surface Equipment Blowout Preventers. Associated Well Control Equipment. Equipment.

Subsea Principles & Procedures

EQA. EQB.

Subsea Equipment SSEQA. SSEQB.

IWCF Drilling Syllabus Level 3 and 4

IWCF WRITTEN DRILLING SYLLABUS LEVEL 3 AND 4 New syllabus category

Original Syllabus Category

L ev eve l 3 Standard

Performance Criteria

OGP Level OGP Level 3 4

L ev eve l 4

ImportanceTheory

PRINCIPLES AND PROCEDURES OVERVIEW WELL CONTROL EVENT A0 01 1 .0 .0 1 U nd nd er er st st an an d t he he ne ne ga ga ti ti ve ve im im pa pa cctt an an d e ff ff ec ec ts ts of of a w el el l c on on tr tr ol ol ev ev en en t. t.

WELL CONTROL TRAINING AND ASSESSMENT A0 1. 1. 02 02 U nd nd er er st st an and t he he ne ne ed ed f or or w el el l con tr tro l t ra ra in ini ng ng a nd nd as se se ss ss me me nt nt.

I de de nt nt ifif y t he he im im pa pa cctt o f a we we llll co co nt nt ro ro l e ve ve nt nt o n: n: - Personal wellbeing - Life and limb - Employment - Environment - Reputation - Society List some of the effects of a well control incident; - Capital loss - Over regulation - Moratorium on drilling - Limiting areas of operations e.g. Arctic

B e a bl bl e t o d is is cu cus s "w hy hy ar e w e h er ere ?" ?" i nc ncl ud ud in in g; g; - Trust of stakeholders - Avoiding over regulation - Recruitment of new personnel - Responsibility to colleagues - Competence

Y

Y

10

10

Y

Y

10

10


New syllabus category

L ev eve l 3


Standard



L ev eve l 4

ImportanceTheory

INTRODUCTION TO WELL CONTROL HYDROSTATIC PRESSURE B01.01 To understand what hydrostatic pressure is. B 01 01 .0 .0 2

T o u nd nd er er st st an an d w ha ha t p ar ar am am et et er er s a ff ff ec ec t h yd yd ro ro st st at at ic ic pr pr es es su su re re an an d h ow ow it it is is calculated.

Be able to define hydrostatic pressure. Be able to identify the parameters that affect hydrostatic pressure and perform calculations.

FORMATION PRESSURE B02.01 To understand what formation pressure is.

Be able to define formation pressure.

B02.02

To un understand wh what ab abnormal fo formation pr pressure is is.

Be ab able to to de define ab abnormal fo formation pr pressure.

To understand what fracture pressure is.

Be able to define fracture pressure.

Y

Y

10

10

Y

Y

10

10

Y

Y

5

5

Y

Y

5

5

Y

Y

5

5

Y

Y

5

5

Y

Y

5

5

N

Y

N/A

3

y

y

5

5

y

y

5

5

FRACTURE PRESSURE B03.01

PRIMARY WELL CONTROL B04.01 To know what primary well control is.

Be able to define primary well control pressure.

B04.02

To know what an influx is.

Be able to define an influx.

B 04 04 .0 .0 3

T o u nd nd er er st st an an d t he he un un ce ce rt rt ai ai nt nt y a rro o un un d i ni ni ti ti al al po po re re an an d f ra ra cctt ur ur e p re re ss ss ur ur e estimation and the potential impact on well control.

Recognise the potential impact of uncertain pore and fracture pressures on well control.

SECONDARY WELL CONTROL B05.01 To know what secondary well control is.

Be able to define secondary well control pressure.

BOP EQUIPMENT B06.01

Be able to identify the uses of BOP equipment.

To know what BOP equipment is used for.







L ev eve l 4

ImportanceTheory

BARRIER CONCEPT C01.01 C01.01

C 01 01 .0 .0 2

To unders understan tand d well well barrie barrierr phil philoso osophy phy in drilli drilling ng and worko workover ver operat operation ions. s.

T o u nd nd er er st st an an d t he he fu fu nc nc titi on on of of a we we llll ba ba rrrr ie ie r e nv nv el el op op e a nd nd th th e r eq eq ui ui re re me me nt nt s for a minimum of two barriers at any time for any given flow path.

Identi Identify fy exampl examples es of primar primary y and and second secondary ary barrie barriers rs in given given well well situ situati ations ons.. Y

Y

5

10

Y

Y

5

10

From a given list sele ct the correct definition of a barrier envelope.







L ev eve l 4

ImportanceTheory

RISK MANAGEMENT D 01 01. 01 01

To un un de de rs rs ta tan d th e m ai ai n co nc nce pt pt of of sy sy st st em em at at ic ic riri sk sk ma ma na nag em eme nt nt .

D01. D01.02 02 D02.01 D02.01

N01.01 N01.01

SURFACE PROBLEMS D03. D03.01 01

I de de nt nt ifify th the pr pri nc nci pl pl es es of of ri ri sk sk ma ma na na ge ge me me nt nt . Identify, analyse (impact, probability), mitigate and control.

To unde unders rsta tand nd the the req requi uire reme ment ntss for for of Mana Manage geme ment nt of of Cha Chang nge e proc proces ess. s.

List List the the ess essen enti tial al rewu rewuir irem emen ents ts for for a Mana Managem gemen entt of Chan Change ge pro proce cedu dure re..

To unde underst rstand and the import importanc ance e of well well cont control rol and emergen emergency cy dril drills ls and and how how to conduct them.

List the purpose, and the steps and generic procedures for well control and emergency drills and the time they should take: - Pit drill. - Trip drill. - Strip drill. - Choke drill. - Diverter drill.

To unde unders rsta tand nd the the imp impor orta tanc nce e of of chec checkl klis ists ts for for any any oper operat atio ion n wit with h well well cont contro roll Given a scenario indicate which factors should be included in a check list. implications.

Y

Y

3

5

Y

Y

5

5

Y

Y

5

5



L ev eve l 3


Standard



L ev eve l 4

ImportanceTheory

CAUSES OF KICKS GENERAL E01.01

To know the causes of kicks.

ABNORMAL FORMATION PRESSURES E02.01 E02.01 F01.01 F01.01 To know know the main main geol geologi ogical cal condi conditio tions ns that that can result result in abnor abnormal mal format formation ion pressures.

LOSS OF HYDROSTATIC PRESSURE E03.01 E03.01 F06.01 F06.01 To know know how to calc calcula ulate te the the reduct reduction ion in hydr hydrost ostati aticc press pressure ure due to to failu failure re to fill the hole. E03.02 E03.02

F06.02 F06.02

E 03 03 .0 .0 3

E 03 03. 04 04

List situations which may cause a kick.

Distinguish between 'Normal' and 'Abnormal' pressures and list the main geological conditions that lead to abnormal formation pressures.

y

y

5

5

Y

Y

2

3

Y

Y

3

5

Y

Y

4

4

Y

Y

2

5

Y

Y

2

4

From well data and fluid density, calculate hydrostatic head.

To know know how to reco recogni gnise se the the cause causess of flui fluid d densit density y reduc reductio tion n in the the drill drilling ing fluid processing and storage systems, e.g. centrifuge removing barite, water dilution.

List the possible causes of fluid density reduction and the checks to be carried out.

T o k no no w h ow ow to to ca ca lc lc ul ul at at e t he he ef ef fe fe ct ct on on hy hy dr dr os os tta a titi c p re re ss ss ur ur e w he he n f lu lu id id s o f different densities are pumped into a hole of known geometry.

From well data and fluid density, calculate hydrostatic head.

To kn kn ow ow th the ca cau se se s of re re du du ce ce d hy dr dr os os ta tat ic ic pr pre ss ss ur ure , e .g .g . - Cement setting - Temperature effects on liquid - Settling of weighting material

List causes of possible reduction of hydrostatic head.

To understa understand nd the the effect effect of of fluids fluids of different different propert properties ies in the choke choke and kill kill lines.

From well data, describe the effect on well control operations and the necessary action(s) to take.

HYDROSTATIC EFFECT

SSE03.05 SSE03.05

SF04.01 SF04.01

SSE0 SSE03. 3.06 06

SSE0 SSE03. 3.07 07

SSE03.08 SSE03.09 SSE03.09

SF06.02 SF06.02

Y

Y

2

5

To unde unders rsta tand nd the the pos possi sibl ble e con conse sequ quen ence cess of of act actio ions ns to be take taken n in in the the even eventt of of From an example of losses, determine the correct initial action to take, a total loss of returns. including; - riser collapse - filling riser from top - riser fill up valve - use of annular to isolate riser.

Y

Y

5

5

To unde unders rsta tand nd the the eff effec ectt of of ris riser er margi margin n on on the the main mainte tena nance nce of bott bottom om hole hole pressure.

Describe the reasons for having a riser margin and how it can affect bottom hole pressure.

Y

Y

3

5

To know how to calculate riser margin.

From well data calculate riser margin and determine if it is possible to increase mud weight sufficiently.

N

Y

N/A

5

To understand understand the problems problems that can occur and know the procedure procedure to be be used during riser disconnect operations.

From specific well data, describe the process of safe disconnect and re-connect of the riser.

Y

Y

2

5







L ev eve l 4

ImportanceTheory

CAUSES OF KICKS GAS CUTTING E03.10 E03.10 F03.01 F03.01

S SE SE 03 03 .1 .1 1

S F0 F0 2. 2. 01 01

LOST CIRCULATION E04.01 E04.01 F04.01 F04.01

E04.02 E04.02

F04.02 F04.02

E 04 04 .0 .0 3

To unde underst rstand and the potent potential ial effe effects cts on hydr hydrost ostati aticc press pressure ure when when drill drilling ing through gas bearing formations.

Describe the effects of gas cut mud on hydrostatic pressure.

T o u nd nd er er st st an an d t he he ef ef fe fe ct ct s o f g as as ex ex pa pa ns ns io io n i n t he he ri ri se se r. r.

De ess cr cr ib ib e t he he ef ef fe fe ct ct s o f g as as ex ex pa pa ns ns io io n i n a su su bs bs ea ea ri ri se se r, r, th th e p ot ot en en ti ti al al pr pr ob ob le le ms ms at surface, the potential impact on bottom hole pressure (BHP) and the appropriate actions to take .

To unde underst rstand and the possib possible le effec effects ts of of a drop drop in in the the level level of drilli drilling ng fluid fluid in the the annulus on the hydrostatic pressure and its potential consequences.

To unders understand tand the actions actions to be taken taken in in the the event event of of a total loss of return returns. s.

T o k no no w t he he p ot ot en en titi al al ca ca us us es es o f l os os t c ir ir cu cu la la ti ti on on , i n t er er ms ms of of bo bo tth h ge ge ol ol og og y a nd nd drilling practices

SWAB AND SURGE EFFECTS E 05 05. 01 01 F 05 05. 01 01 To un un de de rs rs ta tan d th e ca us use s o f sw ab abb in ing an and su sur gi gi ng ng in in a we llll .

E05.02 E05.02

SSE05.03 SSE05.03

F05.02 F05.02

SF03.01 SF03.01

From details of the well condition and drilling fluid density, calculate hydrostatic head at a specific depth and its impact.

Y

Y

4

4

Y

Y

5

5

Y

Y

4

4

Y

Y

5

5

Y

Y

3

5

Y

Y

5

5

Y

Y

5

5

Y

Y

4

4

From an exampl example e of losses, losses, determi determine ne the the correc correctt initial initial action action to take.

From a given list be able to recognise potential causes of lost circulation.

L is is t th e ca us use s o f su rg rg in in g a nd nd sw sw ab abb in ing .

To unde underst rstand and the effect effect of the the foll followi owing ng para paramet meters ers on the the magn magnitu itude de of of swab and surge pressures and how to minimise them: - Well and pipe geometry geometry - Well depth - Fluid characteristics characteristics - Hole conditions and formation properties properties - Tool pulling and running running speeds - Bottom Hole Assembly (BHA) configuration (stabilisers, (stabilisers, packers etc.) - Length of horizontal reservoir reservoir sections

Recognise the parameters and describe the consequences of surging and swabbing on Bottom Hole Pressure (BHP).

To understand understand the causes causes of down-hole down-hole swabbing swabbing resulting resulting from the heave effect on floating rigs.

Describe the consequences of surging and swabbing due to heave effects.







L ev eve l 4

ImportanceTheory

CAUSES OF KICKS TRIPPING E06.01

To understand the need for a trip margin.

E 06 06 .0 .0 2

E06.03

E 06 06 .0 .0 4

E06.05 E06.05

G04.0 G04.01 1

E 06 06 .0 .0 6

E06.07 E06.07

E 06 06 .0 .0 8

E 06 06 .0 .0 9

Y

Y

3

5

Y

Y

2

5

Y

Y

10

5

T o u nd nd er er st st an an d th th e re re qu qu ir ir em em en en ts ts an an d c on on te te nt nt s of of a tr tr ip ip sh sh ee ee t an an d t he he ir ir co co rr rr ec ec t With given data in the form of a trip sheet, interpret what is happening and use the appropriate actions to take.

Y

Y

5

5

To unde underst rstand and incorr incorrect ect fill fill or retu return rn volu volumes mes and and diag diagnos nose e if an an influ influxx may may have occurred.

Y

Y

10

10

Y

Y

4

4

T o u nd nd er er st st an an d t he he al al te te rn rn at at iv iv es es to to de de tte e rm rm in in e t ri ri p m ar ar gi gi n t o m ai ai nt nt ai ai n b ot ot tto om hole pressure while tripping e.g.: - Pressure while drilling tools

Describe some alternative methods to determine appropriate trip margin for given situations such as: - tight pore pressure / fracture margins

Understand th the co correct use of of a tr trip sh sheet.

From gi given tr trip sh sheets recognise ifif there is is any discrepancy that mi might indicate a well control event.

U nd nd er er st st an an d f ac ac to to rs rs wh wh ic ic h m ig ig ht ht re re su su ltlt in in in in flfl ux ux in in th th e d ri ri llll pi pi pe pe .

G04.0 G04.02 2

Describe the reasons for having a trip margin and the procedures to mitigate if not possible to maintain.

Given well data, calculate the correct fill up, calculate impact of not filling hole and describe possible remedial steps. F ro ro m g iv iv en en in in fo fo rm rm at at io io n i de de nt nt ifif y f ac ac to to rs rs th th at at mi mi gh gh t c au au se se in in flfl ux ux in in th th e d ri ri llll pipe.

To unde underst rstand and the differ differenc ence e betwe between en swab swabbed bed kicks kicks in in horiz horizont ontal al and and vertical sections and the appropriate action to take.

Identify the impact in bottom hole pressure and flow given well geometry and swabbing conditions.

Y

Y

3

3

T o u nd nd er er st st an an d th th e ap ap pr pr op op ri ri at at e ac ac titi on on s t o ta ta ke ke fo fo r s wa wa bb bb ed ed ki ki ck ck s i n ho ho ri ri zo zo nt nt al al and vertical sections

identify the best practice to mitigate the risk of swabbing e.g.: - pumping out of hole

Y

Y

3

3

T o u nd nd er er st st an an d th th e ne ne ed ed f or or pr pr ec ec au au titi on on ch ch ec ec ks ks an an d a ny ny co co nt nt in in ge ge nc nc y p la la nn nn in in g prior to pulling non-shearable tubulars through the BOP.

List the checks to be made and what contingencies are appropriate; - flow check

Y

Y

5

5



L ev eve l 3


Standard



L ev eve l 4

ImportanceTheory

KICK WARNING SIGNS AND KICK INDICATORS DEFINITIONS F01.01

To know what is meant by the term kick warning sign.

Be able to define the term kick warning sign.

F01.02

To know what is meant by the term kick indicator.

Be able to define the term kick indicator.

Y

Y

3

3

Y

Y

3

3

Y

Y

5

6

Y

Y

10

5

List the problems associated with monitoring the well on a floating rig and the means to minimise them

Y

Y

4

4

List po possible ki kick wa warning si signs an and st state th the co corre ct ct fifirst ac actions an and th the importance of early detection.

Y

Y

5

5

L is is t po ss ssi bl bl e ki ck ck i nd nd ic ica to tor s a nd nd s ta tat e th e co rr rr ec ect f ir irs t act io io ns ns a nd nd t he he importance of early detection.

Y

Y

5

5

KICKS WHILE DRILLING Kick warning signs and first actions F02.01 F02.01 G01.0 G01.01 1 To know know the poss possibl ible e warni warning ng signs signs that that a well well MIGH MIGHT T be goin going g under under-ba -balan lance, ce, Be able to identify and recognise the parameters that might indicate that a respond correctly and the importance of early detection. well is going under-balance and the importance of early detection. i.e. - Rate of penetration changes - Cuttings size, density and shape - Drilling fluid property changes, e.g. Chlorides - Drilling fluid temperature changes - Connection and background gas - Trip Gas - "Pumps off" Gas - Connection gas Kick indicators and first actions F03. F03.01 01 G02. G02.01 01 To know know the the pos posit itiv ive e ind indic icat atio ions ns of a kic kick: k: - Finger printing connections - Flow from well (pumps off). - Increase in flow from well (pumps on). - Pit volume gain.

SSF03.02 SSF03.02

SG01.01 SG01.01

To understa understand nd the the effect effect of of heave, heave, roll, roll, pitch pitch and and deck deck operation operationss on pit pit level, level, flow rate and flow check monitoring.

Recognise positive kick indicators from rig and well data.

KICKS WHILE TRIPPING Kick warning signs and first actions F04.01 To kn know th the po possible ki kick wa warning si signs wh when tr tripping.

Kick indicators and first actions F 05 05 .0 .0 1 To kn ow ow t he he po si si titi ve ve i nd nd ic ica to tor s o f a k ic ick w hi hi le le t ri ri pp pp in ing .







L ev eve l 4

ImportanceTheory

TOP HOLE DRILLING SHALLOW GAS Definition F10.01

PROCEDURES F10.02 F10.02 F02.01 F02.01

F 10 10 .0 .0 3

F10.04 F10.04

K07.01 K07.01

To know what is meant by the term shallow gas.

Define what shallow gas is.

To unde underst rstand and the means means requ require ired d to cont control rol critic critical al dril drillin ling g param paramete eters rs when when drilling top hole, to prevent a shallow gas influx.

Define the critical parameters when drilling top hole. e.g.: - penetration rate, - drilling fluid density, - trip speed - pump rate - hole diameter - kill mud

Y

Y

5

5

Y

Y

5

5

T o u nd nd er er st st an an d t he he ad ad va va nt nt ag ag es es an an d d is is a ad d va va nt nt ag ag es es of of ri ri g t yp yp es es in in sh sh al al lo lo w g as as areas.

For a given scenario identify the advantages and disadvantages of a given rig type in shallow gas areas.

N

Y

N/A

3

To know know the step-b step-by-s y-step tep proced procedure ure to be be follo followed wed in orde orderr to secure secure the safety of the personnel and rig when a shallow gas kick is in progress.

List the step-by-step procedure to be followed by rig personnel when a shallow gas kick is in progress.

Y

Y

5

5

To underst understand and the the advantag advantages es and and disadvan disadvantages tages of drilling drilling top hole hole with or without a riser.

Analyse the basic principles only; - move off quickly - no gas directly to the rig - avoid collapse of riser

N

Y

2

4

Y

Y

5

5

Y

Y

5

5

TOP HOLE DRILLING

SSF10.05 SSF10.05

SSF10.06

SF01.01 SF01.01

To understand the methods to limit the potential for shallow gas kicks and the means to detect them.

Identify the method to limit the potential for shallow gas kicks; - heavy mud - available - pilot hole - anchors - rig move - control rate of penetration - pump rate/AV - pump out hole - monitor - visual (ROV) and sonar - surface visual

SSF1 SSF10. 0.07 07

To unde unders rsta tand nd the the imp impli lica cati tion onss of of gas gas rea reach chin ing g the the riser riser (or (or com comin ing g out out of solution) above the BOP and on the appropriate actions to take. To understand the consequences and risks involved in having the diverter system tied into the MGS.

In a given situation identify the appropriate course of action.







L ev eve l 4

ImportanceTheory

CIRCULATING SYSTEM DEFINITION AND PRINCIPLES G01.01 To understand what the circulating system is.

Be able to describe sections of a circulating system.

G0 1. 1. 02 02

To un de de rs rs ta ta nd nd pr es es su sur e l os os se se s a ro ro un un d a ci rc rcul at at in ing s ys ys te te m. m.

I de de nt nt ifify t he he c au au se se s of pr es es su sur e l os oss es es i n a ci rc rcu la titi ng ng sy st st em em.

G0 1. 1. 03 03

U nd nd er er st st an and th the ef ef fe fe ct ct s o f p re re ss ss ur ure lo lo ss ss es es in in a ci rc rcu la la titi ng ng sy sys te te m. m.

D es es cr cri be be th th e e ff ffe ct ct s o f p re re ss ssu re re lo los se se s on ; - surface gauge pressures - bottom hole pressures

G 01 01 .0 .0 4

Y

N

5

N/A

Y

Y

3

5

Y

Y

3

5

Y

Y

1

5

Y

Y

1

5

Y

Y

1

5

Select the equipment and well-bore conditions that can determine the choice of a specific slow circulation rate.

N

Y

N/A

4

T o u nd nd er er st st an an d th th e re re as as on on s f or or n ee ee di di ng ng t o m ea ea ssu u re re a nd nd re re co co rd rd s lo lo w c ir ir cu cu la la titi ng ng rates.

From a given list be able to identify the reasons for using slow circulating rates for well control operations.

Y

Y

2

5

To know know how to acc accura uratel tely y reco record rd slow slow circul circulati ating ng pres pressur sures, es, and when when and and how often this should be performed during drilling operations.

Demonstrate ability to record system pressure losses at different pump rates and fluid densities and identify appropriate line ups for slow circulating rates.

Y

Y

3

3

To know know how to calc calcula ulate te the the appro approxim ximate ate pres pressur sure e chang changes es resul resultin ting g from from changes in pump speed and/or drilling fluid density.

Given pump speed, drilling fluid density and pressure calculate the new pump pressure when changing the pump speed and/or drilling fluid density.

Y

Y

2

5

To know know how how to record pressure pressure losses losses in the choke choke and and kill kill lines lines at slow circulating rates when drilling with a subsea BOP stack.

Demonstrate ability to record or analyse pressure losses in the choke and kill lines and determine the effect on bottom hole pressure.

Y

Y

3

5

U nd nd er er st st an an d bo bo tttt om om h ol ol e ci ci rc rc ul ul at at in in g pr pr es es su su re re a nd nd e qu qu iv iv al al en en t ci ci rc rc ul ul at at in in g density.

Given well data, calculate bottom hole circulating pressure and equivalent circulating density.

G01. G01.05 05

Unde Unders rsta tand nd the the rel relat atio ions nshi hip p betw between een pump pump pres pressu sure re and and pum pump p spe speed ed..

Desc Descri ribe be and and cal calcu cula late te how how cha chang nges es in pump pump speed speed affe affect ct pres pressu sure res. s.

G01. G01.06 06

Unde Unders rsta tand nd the the rel relat atio ions nshi hip p betw between een pump pump pres pressu sure re and and mud mud dens densit ity. y.

Desc Descri ribe be and and cal calcu cula late te how how cha chang nges es in mud mud den densi sity ty affe affect ct pres pressu sure res. s.

SLOW CIRCULATION RATES G02.01 G02.01 E01.01 E01.01 To unde underst rstand and how well well bore bore and and pump pump parame parameter terss influ influenc ence e the the choic choice e of slow circulation rates. G 02 02 .0 .0 2

G02.03 G02.03

G02.04 G02.04

SSG02.05 SSG02.05

E01.02 E01.02

E01.04 E01.04

SE01.01 SE01.01



L ev eve l 3


Standard



L ev eve l 4

ImportanceTheory

FRACTURE PRESSURE AND MAXIMUM SURFACE PRESSURES H01.01 H01.02 H01.02

H01.03 H01.03

H01.04 H01.04

To understand what fracture pressure is. E02.02 E02.02

E02.01 E02.01

E02.03 E02.03

Be able to define fracture pressure.

To unde underst rstand and why leak leak off off tests tests are are under undertak taken en and and the the differ differenc ence e betwee between n a Be able to say what a leak off test measures and identify instances when a leak leak off test and a formation integrity test. off test result is unacceptable. From a list indicate the critical well control parameters affected in a higher risk direction by not achieving the target Formation Integrity Test (FIT)/Leak Off Test (LOT) value (Kick tolerance, MAASP). To know know how to line line up up for for a leakleak-off off test, test, how how to to instr instruct uct the pump pump opera operator tor,, and how to apply the correct procedure with respect to pump speed, volume pumped and method (intermittent and/or continuous) of pumping.

Given rig information and well data, indicate specific requirements to perform an acceptable leak-off test (hook-up, instructions and method of pumping).

To know know how to reco record rd and and inte interpr rpret et the the press pressure ure vers versus us volu volume me graph graph from from the leak-off test, and identify the leak-off point and its impact.

From a leak-off test plot, indicate at which point on the graph leak-off takes place and interpret the results.

H 01 01 .0 .05

E0 3. 3. 01 01

To kn ow ow h ow ow t o o bt bt ai ai n M AA AAS P f ro ro m l ea eak -o -o ff ff t es es t re su su ltlt s. s.

F ro rom a se t o f we llll da ta ta, ca lc lcul at at e t he he MA MA AS AS P. P.

H01. H01.06 06

E03. E03.02 02

To unde unders rsta tand nd how how oft often en and and why why MAA MAASP SP mus mustt be be reca recalc lcul ulat ated ed..

From From a list list of para parame mete terr cha chang nges es,, indi indica cate te whi which ch ones ones wil willl nec neces essi sita tate te a new new MAASP calculation, e.g. drilling fluid density, leak-off test etc.

H01.07 H01.07

H 01 01 .0 .0 8

E03.03 E03.03

To unde underst rstand and how MAASP MAASP chan changes ges duri during ng well well cont control rol operat operation ionss and and when when initial MAASP is no longer applicable.

From a given list indicate the factors that influence MAASP during well control operations.

T o u nd nd er er st st an an d t he he i mp mp or or ta ta nc nc e a nd nd pr pr in in ci ci pl pl es es of of ki ki ck ck ma ma rrg g in in /t /t ol ol er er an an ce ce a nd nd how it is applied to well operations.

Identify the factors affecting kick tolerance and their impact on well operations for a given scenario. Be able to define acceptable limits.

Y

Y

5

5

Y

Y

2

4

N

Y

N/A

3

N

Y

N/A

4

Y

Y

1

10

N

Y

N/A

4

Y

Y

2

4

Y

Y

4

10

N

Y

N/A

2

NORMAL AND ABNORMAL PRESSURES

S SH SH 01 01 .0 .0 9

T o u nd nd er er st st an an d t he he ef ef fe fe ct ct of of wa wa te te r d ep ep th th on on fo fo rm rm at at io io n s ttrr en en gt gt h. h.

De ess cr cr ib ib e h ow ow in in cr cr ea ea ssii ng ng wa wa te te r d ep ep th th af af fe fe ct ct s f or or ma ma ti ti on on st st re re ng ng th th . List possible solutions to mitigate this.



L ev eve l 3


Standard



L ev eve l 4

ImportanceTheory

INFLUX CHARACTERISTICS AND BEHAVIOUR PRINCIPLES I 01 01 .0 .0 1

T o k no no w t he he di di ff ff er er en en t t yp yp es es of of in in flfl ux ux an an d t he he ha ha za za rrd d s t he he y p re re se se nt nt .

I de de nt nt ifif y t he he di di ff ff er er en en t t yp yp es es of of in in flfl ux ux fl fl ui ui ds ds an an d t he he re re la la te te d h az az ar ar ds ds ; - gas (hydrocarbon, H 2S, CO2) - oil - water

I 01 01 .0 .0 2

U nd nd er er st st an an d h ow ow an an in in flfl ux ux ma ma y c ha ha ng ng e a s i t i s c ir ir cu cu la la te te d u p a we we llll .

D es es cr cr ib ib e t he he ch ch an an ge ge s w hi hi ch ch ma ma y t ak ak e p la la cce e as as di di ff ff er er en en t t yp yp es es of of in in flfl ux ux ar ar e circulated.

I01.03

Understand basic gas law and w hy hy it is important. Gas Laws P1V1 = P2V2

Calculate pressure and volume at surface from given data.

I02.04

Understand influx migration.

Describe what may happen when the well is shut in if an influx migrates; - in an open well - in a shut in well.

INFLUX BEHAVIOUR I 02 02 .0 .0 1

I02.02 I02.02

I02.03 I02.03

I02.04 I02.04

G03.0 G03.01 1

G03.0 G03.03 3

G03.0 G03.02 2

I 02 02 .0 .0 5

I02.06 I02.06

G03.0 G03.04 4

T o u nd nd er er st st an an d t he he be be ha ha vi vi ou ou r o f a hy hy dr dr oc oc ar ar bo bo n g as as in in flfl ux ux in in wa wa te te r b as as ed ed drilling fluid.

Describe how a hydrocarbon influx will behave as it is circulated in a well and state the effects on; - volumes - pressures

To unde underst rstand and the solubi solubilit lity y of hydroc hydrocarb arbon, on, carbon carbon dioxid dioxide e and hydrog hydrogen en sulphide gases when mixed under down hole conditions with water based or (pseudo) oil based drilling fluid.

Recognise the downhole conditions under which hydrocarbon, carbon dioxide, or hydrogen sulphide gases are likely to go into solution, and come out of solution (bubble point) with water based and/or oil based drilling fluid.

To unde underst rstand and the behavi behaviour our of diss dissolv olved ed gas gas in diff differe erent nt dril drillin ling g fluid fluid types types when circulating the influx to surface including the effects of temperature and pressure.

For different drilling fluid types describe how dissolved gas will behave under specific downhole conditions, how and when dissolved gas will evolve out of the drilling fluid if the influx is circulated to surface and list the possible subsequent consequences.

To unde underst rstand and the impac impactt of hydr hydroca ocarbo rbon n gas gas compr compress essibi ibilit lity y under under down downhol hole e conditions on its state (gas or liquid) and migration rate.

List the possible effects of gas compressibility under downhole conditions.

T o u nd nd er er st st an an d t he he ac ac titi on on s r eq eq ui ui re re d t o m it it ig ig at at e t he he ef ef fe fe ct ct s o f g as as br br ea ea k o ut ut e.g.: - Shut in Well - circulate bottom up through chokes

Describe the different actions required to mitigate the potential impacts of gas break out.

To unde underst rstand and the behavi behaviour our of gas gas in in relat relation ion to hori horizon zontal tal and vertic vertical al sections.

Describe the differences likely to occur in different kick situations and understand that gas will not normally behaviour according to "ideal" gas law predictions.

Y

Y

5

5

Y

Y

5

10

Y

Y

5

10

Y

Y

5

10

Y

Y

5

5

Y

Y

3

3

Y

Y

5

Y

Y

2

3

Y

Y

5

5

N

Y

N/A

5

5







L ev eve l 4

ImportanceTheory

SHUT IN PRODECURES GENERAL PRINCIPLES J01.01

To understand is meant by the term shut in procedure.

Be able to define wh what a shut in procedure is.

To unde underst rstand and the steps steps take taken n to shut shut a well well in usin using g the the hard hard shut shut-in -in method method (as described in API Recommended Practice No. 59), in different operational situations.

List the steps taken to shut a well in, in accordance accordance with the hard shut-in method, for the following situations:-

Y

Y

10

10

Y

Y

10

5

Y

Y

5

10

Y

Y

5

5

Y

Y

3

3

Y

Y

5

5

Y

Y

3

5

PROCEDURE J02.01 J02.01

H02.01 H02.01

- Drilling on bottom. - Tripping in/out of the hole. - Running casing. - Cementing. - Wireline operations. - Running completion. J 02 02 .0 .0 2

T o u nd nd er er st st an an d h ow ow t o i nt nt er er pr pr et et an an d r es es po po nd nd to to w he he tth h er er th th e s hu hu t i n h as as worked.

List the steps taken to ensure the well is shut in and the appropriate action to take if not; - Monitor on trip tank. - Verify line up. - Flow meter. - Pressures.

SSJ02.03 SSJ02.03

SH01.01 SH01.01

To understa understand nd the the steps steps taken taken to shut a well in from from a floati floating ng vessel vessel using using the the hard shut in method (as described in API Recommended Practice No. 59), in different operational situations and understand the advantages and disadvantages of hanging off the drill string on the pipe rams for moored and dynamically positioned rigs.

WIRELINE OPERATIONS J 03 03 .0 .0 1 T o k no no w t he he ef ef fe fe ct ct of of w ir ir el el in in e a nd nd t oo oo l m ov ov em em en en t ha ha s o n t he he bo bo tttt om om ho ho le le pressure in an open reservoir.

List the steps taken to shut a well in, in accordance with the hard shut-in method, for the following situations:- drilling on bottom, - tripping in/out of the hole, - running casing, - cementing, - wireline operations, and identify advantages and disadvantages of hanging off the pipe.

Identify the potential effect of wireline movement on bottom hole pressure.

J03.02

To know how to shut in the well during wire liline operations.

Identify the correct steps to shut in the well.

J 03 03 .0 .0 3

T o u nd nd er er st st an an d t he he lili mi mi ta ta titi on on s o f B OP OP (a (a nn nn ul ul ar ar an an d s he he ar ar ra ra m mss ) d ur ur in in g w ir ir el el in in e Identify limitations of BOP (annular and shear rams) during wireline operations. operations.




INTERPRETATION J 04 04 .0 .0 1

J04.02 J04.02

J02.0 J02.01 1


T o k no no w w hy hy pr pr es es su su re re s m us us t b e r ec ec or or de de d o nc nc e t he he we we llll is is sh sh ut ut in in .

To unde underst rstand and the possib possible le reas reasons ons for differ differenc ences es betw between een Shut Shut In Drill Drill Pipe Pipe (or String) Pressure and Shut In Casing (or Annulus) Pressure.


B e a bl bl e t o d es es cr cr ib ib e w hy hy pr pr es es su su re re s a rre e re re co co rd rd ed ed af af tte e r t he he we we llll ha ha s b ee ee n s hu hu t in.

OBSERVATIONS J 05 05 .0 .0 1

J05.02 J05.02

J05.03 J05.03

J01.0 J01.01 1

J01.0 J01.02 2

INFLUX MIGRATION J06.01 J06.02 J06.02

J06.03 J06.03

J 06 06 .0 .0 4

J01.0 J01.03 3

J01.0 J01.04 4

T o u nd nd er er st st an an d in in st st an an ce ce s wh wh en en sh sh ut ut i n p re re ss ss ur ur es es ma ma y i nd nd ic ic at at e no no nn- ki ki ck ck e ve ve nt nt s and the appropriate actions to take.

From given data interpret potential causes and appropriate actions; - supercharging - trapped pressure

T o k no no w h ow ow to to de de tte e rm rm in in e t he he Sh Sh ut ut in in Dr Dr ilil l P ip ip e P re re ss ss ur ur e w it it h a flfl oa oa t v al al ve ve present in the drill string.

Given a kick situation with well data, demonstrate how to determine the Shut in Drill Pipe Pressure with a float valve installed.

To unders understan tand d the the limi limitat tation ionss of of a pressu pressure re gauge gauge and and know know how they they shou should ld be read.

To identify the limitation of pressure gauges in the given circumstances.

To unders understan tand d the the poss possibl ible e diffe differen rence ce in pres pressur sure e readi readings ngs which which can result result from taking Shut in Drill Pipe Pressure and Shut in Casing Pressure at different gauges on the rig and the importance of accurate calibration.

From a schematic drawing of a standpipe and choke line systems with pressure gauges at different locations, explain the reason for different pressure readings (e.g. attach different values to certain gauges in the system).

To know what is meant by the term gas migration.

Be able to define gas migration.

To unde underst rstand and the possib possible le caus causes es for for a pressu pressure re incr increas ease e with with time time in in a shut shut-in well.

Describe the causes of pressure changes in a shut in well.

To know know the actio actions ns to to take take when when there there are are indi indica catio tions ns of of influ influxx migra migratio tion n in a closed well.

Given a kick situation with well data, describe the appropriate actions to take when influx migration takes place in a closed well.

T o u nd nd er er st st an an d h ow ow to to co co nt nt ro ro l pr pr es es su su re re w he he n an an in in flfl ux ux i s m ig ig ra ra titi ng ng .

L ev eve l 4

ImportanceTheory

Y

Y

5

5

Y

Y

1

5

N

Y

N/A

3

Y

Y

2

4

Y

Y

2

4

Y

Y

2

4

Y

Y

2

5

Y

Y

2

5

N

Y

N/A

5

N

Y

N/A

4

Given well and/or kick data, provide interpretation of the difference between Shut In Drill Pipe Pressure and Shut In Casing Pressure. - Influx density - Cuttings loading - Density of influx greater than drilling fluid - Position of bit and or pipe - Flow through the drill string - Blockage in the annulus - Inaccuracy of the gauges - Well deviation - Mud properties

J 04 04 .0 .0 3


C al al cu cu la la te te t he he v ol ol um um e to to be be b le le d o ff ff , c or or re re sp sp on on di di ng ng t o p re re ss ss ur ur e in in cr cr ea ea sse e.



L ev eve l 3


Standard



L ev eve l 4

ImportanceTheory

WELL CONTROL METHODS PRINCIPLES K01.01

To know what is meant by the term kill methods.

Be able to define and list kill methods.

Y

Y

5

5

K01.02

To know the difference between kill and control

Be able to define and list well control methods.

Y

Y

5

5

Describe Describe the effects effects of different different kill pump rates with regard regard to formation formation strength, annular friction loss, choke operator reaction time, barite delivery time and pump pressure limitations.

N

Y

N/A

4

To know know how to sele select ct the the most most approp appropria riate te kill kill method method with with the the bit bit on bottom.

Given a set of well bore conditions, but with the bit on bottom, select a kill method and explain the choice.

N

Y

N/A

3

To be be able able to to selec selectt the the most most appr appropr opriat iate e cours course e of action action when when tripp tripping ing or not on bottom.

Given a set of well bore conditions, and while tripping or not on bottom, select and reason the safest course of action to be followed.

N

Y

N/A

3

To know know how to brin bring g the the pump pump up up to kill kill speed speed while while main maintai tainin ning g botto bottom m hole pressure constant.

Given well and kick data, demonstrate how to bring the pump up to kill speed while maintaining bottom hole pressure constant.

N

Y

2

10

T o u nd nd er er st st an an d t he he po po ss ss ib ib le le ac ac titi on on s w hi hi ch ch ca ca n b e t ak ak en en to to re re du du ce ce pr pr es es su su re re at at the weak zone.

List the possible actions that can be taken to reduce pressure at the weak zone, e.g. during start up of pumps. Driller to communicate and be aware of their influence when bringing pumps up to speed e.g. holding casing pressure constant with appropriate appropriate margin.

N

Y

N/A

4

N

Y

2

10

N

Y

3

5

N

Y

3

5

Y

Y

3

5

KILL METHOD PRINCIPLES K02.01 K02.01 K01.01 K01.01 To know how to select select kill pump rate.

K02.02 K02.02

K02.03 K02.03

K02.04 K02.04

K01.02 K01.02

K01.03 K01.03

K01.04 K01.04

K 02 02 .0 .0 5

K02.06 K02.06

K01.06 K01.06

To know know how to chan change ge pump pump speeds speeds and shut shut down down a kill kill opera operatio tion n while while maintaining bottom hole pressure constant.

Given well and kick data, shut down the kill operation while maintaining bottom hole pressure constant.

CHOKE LINE FRICTION

SSK02.07 SSK02.07

SSK02.08 SSK02.08

SSK0 SSK02. 2.09 09

SK03.01 SK03.01

SK03.02 SK03.02

To understa understand nd how to start start the kill operations operations taking taking into account account the effect effect of Given well and kick data, demonstrate how to bring the pumps up to kill speed Choke Line Friction. while maintaining bottom hole pressure constant, by taking into account the effect of Choke Line Friction on the (Dynamic) Casing Pressure Gauge or by using the (Static) Kill Line Pressure Gauge To know know how to to change change pump speed and shut shut down down a kill operation operation taking taking into account the effect of Choke Line Friction, and maintaining bottom hole pressure constant.

Given well and kick data, demonstrate how to change pump speed or shut down a kill operation while maintaining bottom hole pressure constant, by taking into account the effect of Choke Line Friction the (Dynamic) Casing Pressure Gauge or by using the (Static) Kill Line Pressure Gauge

To know know the the add addit itio iona nall mea measu sure ress whi which ch can can be be tak taken en to miti mitiga gate te for for the the effects of choke line friction.

List the advantages of having additional sensors on ther BOP.



L ev eve l 3


Standard



L ev eve l 4

ImportanceTheory

WELL CONTROL METHODS WAIT & WEIGHT AND DRILLERS METHODS K03.0 K03.01 1 K02.01 K02.01 To know know the step step by step step proce procedur dure e requi required red to carr carry y out out the the Wait Wait and and Weight method and the Driller's Method.

K 03 03 .0 .0 2

SSK03.03 SSK03.03

T o k no no w t he he ad ad va va nt nt ag ag es es an an d d is is a ad d va va nt nt ag ag es es of of th th e D ri ri llll er er 's 's an an d W ai ai t a nd nd Weight methods.

SK01.01 SK01.01

S SK SK 03 03 .0 .0 4

SSK0 SSK03. 3.05 05

SK04 SK04.0 .01 1

Identify the steps of the Driller's and Wait and Weight methods.

Given well data analyse the advantages and disadvantages relating to the use of the Wait and Weight Method or Driller's Method to remove an influx from the well. (N.B. Driller acting under direction of the Supervisor.)

To know know the step step by by step step procedure procedure required required to carry out out the the Driller' Driller'ss Method Method and the Wait and Weight method, and demonstrate the capability to perform them when drilling with a subsea BOP installed with reference to the length of kill and choke lines.

Given well and kick data, demonstrate how to bring the pumps up to kill speed while maintaining bottom hole pressure constant. Take into account the effect of choke line friction on the (Dynamic) Casing Pressure Gauge or by using the (Static) Kill Line Pressure Gauge.

T o r ec ec og og ni ni se se t he he p ot ot en en ti ti al al e ff ff ec ec t of of g as as t ra ra pp pp ed ed b en en ea ea th th a BO BO P i f no no t removed.

List the potential consequences of not removing trapped gas.

To kno know w the the proc proced edur ure e for for remov removin ing g gas gas trap trappe ped d in a sub subse sea a BOP. BOP.

Desc Describ ribe e and and demo demons nstr trat ate e the the proc proced edur ure e for for remo removin ving g trap trappe ped d gas gas from from beneath a BOP or in a riser.

Y

Y

2

5

N

Y

N/A

3

Y

Y

3

5

Y

Y

3

5

Y

Y

2

5



L ev eve l 3


Standard



L ev eve l 4

ImportanceTheory

WELL CONTROL METHODS KILL SHEETS Perform kill sheet calculations K04.01 To know what a kill sheet is. K04. K04.02 02

SSK0 SSK04. 4.03 03

L01. L01.00 00

SL01 SL01.0 .00 0

To kno know w how how to comp comple lete te a Sur Surfa face ce BOP BOP kil killl sheet sheet from from wel welll data data..

To kno know w how how to com compl plet ete e a Subs Subsea ea BOP BOP kil killl shee sheett from from wel welll data data..

Describe the key elements on a kill sheet and why it is required. Comp Complet lete e a kil killl sheet sheet base based d on vert vertic ical al,, devi deviat ated ed or or hori horizo zont ntal al wel welll data data and and answer calculation questions based on Standards K04.04 through K04.19.

Comp Comple lete te a kil killl shee sheett base based d on verti vertica cal, l, dev devia iate ted d or hor horizo izont ntal al wel welll data data and and answer calculation questions based on Standards K04.04 through K04.19 plus Standards SSK04.20 through SSK04.22.

Y

N

5

N/A

Y

Y

Y

Y

4

4

Perform calculations K04.04

L01.02

Formation p re re ss ssure.

Y

Y

2

2

K 04 04 .0 .0 5

L 01 01 .0 .0 7

H yd yd ro ro st st at at ic ic an an d Bo Bo tttt om om H ol ol e pr pr es es su su re re .

Y

Y

4

4

K 04 04 .0 .0 6

L 01 01 .0 .0 8

F ra ra cctt ur ur e a nd nd Le Le ak ak -o -o ff ff p re re ss ss ur ur e. e.

Y

Y

2

4

K04.07

L01.10

Kill flfluid density.

Y

Y

5

10

K 04 04 .0 .0 8

L 01 01 .1 .1 2

B ot ot tto o ms ms up up ti ti me me fo fo r n or or ma ma l d ri ri llll in in g. g.

Y

Y

2

2

K04. K04.09 09

L01. L01.13 13

Tota Totall circ circul ulat atin ing g time, time, inc inclu ludi ding ng sur surfa face ce equ equip ipme ment nt..

Y

Y

2

2

K04.10

L01.14

Surface to to bi bit titime.

Y

Y

5

5

K04.11

L01.15

Bit to to sh shoe ti time.

Y

Y

5

5

K04.12

L01.16

Bottom up strokes

Y

Y

4

4

K 04 04 .1 .1 3

L 01 01. 17 17

S ur ur fa fa ce ce t o bi t s tr tro ke ke s

Y

Y

5

5

K04.14

L01.18

Bit to shoe stroke s

Y

Y

5

5

K04. K04.15 15

L01. L01.19 19

Tota Totall circu circula lati ting ng stro stroke kes, s, incl includ udin ing g surfa surface ce equi equipm pmen ent. t.

Y

Y

2

2

K04.16

L01.24

MAASP.

Y

Y

3

5

K 04 04 .1 .1 7

L 01 01 .2 .2 9

I ni ni ti ti al al c ir ir cu cu la la ti ti ng ng p re re ss ss ur ur e. e.

Y

Y

2

5

K 04 04 .1 .1 8

L 01 01. 30 30

F in ina l ci ci rc rcu la la titi ng ng p re re ss ss ur ure .

Y

Y

2

5

K 04 04 .1 .1 9

L 01 01. 31 31

P re re ss ss ur ur e d ro ro p p er er s te te p. p.

Y

Y

2

5

SSK04 SSK04.20 .20

SL01.0 SL01.02 2

Volume Volume and fluid fluid requi required red to disp displac lace e the the Riser Riser..

Y

Y

4

4

SSK0 SSK04. 4.21 21

SL01 SL01.0 .06 6

Dyna Dynami micc casi casing ng pres pressu sure re

Y

Y

3

5

Dynamic MAASP

Y

Y

3

5

SSK04.22



L ev eve l 3


Standard



L ev eve l 4

ImportanceTheory

WELL CONTROL METHODS VOLUMETRIC METHOD K05.01 To kn know wh what is is meant by by the te term vo volumetric method.

Be ab able to to describe th the vo volumetric method.

K05.0 K05.02 2

To know know the the stepstep-byby-ste step p proced procedure ure requ require ired d for contro controlli lling ng a well well accor accordin ding g to the volumetric principle.

Describe how the volumetric method can be applied.

To unde underst rstand and when when the the volum volumetr etric ic meth method od is is the the appro appropri priate ate well well contr control ol technique.

List some situations when the volumetric method should be applied.

T o kn kn ow ow t he he s te te pp- by by -s -s tte e p pr pr oc oc ed ed ur ur e re re qu qu ir ir ed ed f or or c on on tr tr ol ol lili ng ng a w el el l ac ac co co rd rd in in g to the lubricate and bleed principle.

Describe how the lubricate and bleed method can be applied.

T o u nd nd er er st st an an d w he he n t he he l ub ub ri ri ca ca te te an an d b le le ed ed me me tth h od od is is th th e a pp pp ro ro pr pr ia ia te te we we llll control technique.

List some situations when the lubricate and bleed method should be applied.

To know what is meant by stripping.

Be able to define stripping.

T o k no no w t he he s te te pp- by by -s -s tte e p pr pr oc oc ed ed ur ur e fo fo r a s tr tr ip ip pi pi ng ng op op er er at at io io n. n.

L is is t th th e st st ep ep -b -b yy- st st ep ep pr pr oc oc ed ed ur ur e of of a st st ri ri pp pp in in g o pe pe ra ra titi on on .

To kno know w the the fact factor orss that that lim limit it or or comp compli lica cate te the the abi abili lity ty str strip ip in in the the hole. hole.

Iden Identi tify fy the the lim limit itat atio ions ns or or comp compli lica cati tion onss that that aff affec ectt the the abil abilit ity y to stri strip p in the the hole.

K05.03 K05.03

K04.01 K04.01

K04.02 K04.02

K 05 05 .0 .0 4

K 05 05 .0 .0 5

STRIPPING K06.01 K 06 06 .0 .0 2 K06. K06.03 03

K 05 05 .0 .0 1

Y

Y

2

5

N

Y

N/A

5

N

Y

N/A

3

N

Y

N/A

5

N

Y

N/A

3

Y

Y

5

5

Y

Y

2

5

N

Y

N/A

3







L ev eve l 4

ImportanceTheory

WELL CONTROL DURING CASING AND CEMENTING OPERATIONS RUNNING AND PULLING CASING L 01 01 .0 .0 1 T o k no no w t he he f ac ac to to rs rs th th at at in in cr cr ea ea sse e t he he r is is k o f k ic ic ks ks oc oc cu cu rr rr in in g w he he n r un un ni ni ng ng a nd nd pulling casing.

Select the factors that increase the risk of kicks occurring when running and pulling casing.

L 01 01 .0 .0 2

T o u nd nd er er st st an an d t he he ac ac titi on on s t ha ha t w ilil l m it it ig ig at at e s wa wa b a nd nd su su rg rg e p re re ss ss ur ur e w he he n running and pulling casing.

Select what actions will mitigate surge and swab pressures.

L 01 01 .0 .0 3

To un un de de rs rs ta tan d th e a dv dv an an ta tag es es of of a s el el f fi llll in in g f lo loa t sy sy st ste m. m.

S el el ec ec t t he he ad adv an an ta tag es es a nd nd d is isa dv dva nt nt ag ag es es of of a se lflf f ilil lili ng ng flfl oa oa t s ys ys te te m. m.

L 01 01 .0 .0 4

R ec ec og og ni ni se se w he he n a s el el f f ilil lili ng ng f lo lo at at f ai ai ls ls t o c on on ve ve rt rt a nd nd t o k no no w t he he consequences.

Identify the consequences of a self filling float failing to convert.

L 01 01 .0 .0 5

T o u nd nd er er st st an an d h ow ow re re ttu u rn rn s s ho ho ul ul d b e m on on itit or or ed ed wh wh en en ru ru nn nn in in g a nd nd pu pu llll in in g casing.

Describe how to monitor returns.

L 01 01 .0 .0 6

To kn kn ow ow ho ho w to ca ca lc lcul at at e d is isp la la ce ce me me nt nt s w he he n r un un ni ni ng ng ca ca si si ng ng .

L 01 01 .0 .0 7

T o k no no w w ha ha t a cctt io io ns ns sh sh ou ou ld ld be be ca ca rrrr ie ie d o ut ut ifif mi mi no no r, r, ma ma jjo o r o r t ot ot al al lo lo ss ss es es occur when running casing.

CEMENTING CASING AND LINER L 02 02 .0 .0 1 T o k no no w t he he ef ef fe fe ct ct o n t he he b ot ot tto o m h ol ol e p re re ss ss ur ur e d ur ur in in g a c em em en en ti ti ng ng operation. L 02 02 .0 .0 2

T o u nd nd er er st st an an d t he he im im po po rt rt an an ce ce of of ge ge tttt in in g a su su cc cc es es sf sf ul ul ce ce me me nt nt in in g j ob ob an an d t he he potential consequences of failure.

F ro ro m g iv ive n i nf nfo rm rm at at io ion ca cal cu cu la la te te op op en en an an d c lo los ed ed en en d d is isp la la ce ce me me nt nt s. s.

Y

Y

4

4

Y

Y

4

4

Y

Y

2

4

Y

Y

3

4

Y

Y

5

5

Y

Y

5

5

Describe the appropriate actions required if minor, major or total losses occur when running casing.

Y

Y

4

4

Identify changes that occur in bottom hole pressure during a cementing operation.

Y

Y

3

5

Select the correct statements that affect the quality of cement placement and indications of success. List the indicators for a successful cement job: - Correct pressure profile - Correct returns - Plugs bump at right time - No back flow - Right weight and quantity - Successful pressure test

Y

Y

2

5

L 02 02 .0 .0 3

T o u nd nd er er st st an an d t he he po po ss ss ib ib le le se se qu qu en en ce ce of of ev ev en en ts ts th th at at co co ul ul d a llll ow ow fo fo rm rm at at io io n fluids to enter the casing or open hole casing annulus.

Select events that could result in formation fluid entering the casing or open hole casing after a cementing operation.

N

Y

N/A

5

L 02 02 .0 .0 4

T o u nd nd er er st st an an d t he he st st ep ep s t o t ak ak e i f a we we llll st st ar ar ts ts to to fl fl ow ow du du ri ri ng ng a c em em en en titi ng ng operation.

Select the procedures required to shut in a well for the following situations:- while cementing is being displaced. - while waiting on cement.

Y

Y

5

5

Y

Y

5

5

SHUT IN PROCEDURES WHEN RUNNING CASING L03.01 To un understand th the st steps taken to sh shut in in a well.

List th the st steps taken to sh shut a well in in for the fo following si situations:- Running casing. - While rigging up cementing equipment.



L ev eve l 3


Standard



L ev eve l 4

ImportanceTheory

WELL CONTROL MANAGEMENT PRIOR TO COMMENCING M01. M01.01 01 To unde unders rsta tand nd the the imp impor orta tanc nce e of of chec checkl klis ists ts for for any any oper operat atio ion n wit with h well well cont contro roll Given a scenario indicate which factors should be included in a check list. implications.

DURING THE KILL M02.01 N01.02

M02. M02.02 02

To know how to instruct and conduct the practice of performing different well control operations.

To unde unders rsta tand nd the the impl implic icat atio ions ns and and pote potent ntia iall of indi indica cati tion onss that that MAAS MAASP P has has been exceeded during a well control operation; - Minor losses - Major losses - Total losses

Demonstrate the method and steps required to strip drill pipe in or out of the hole, e.g.:- Lining up - BOP operation. - Preparation and lubrication of tooljoint. - Volumetric calculation versus choke pressures. - Compensation for closed end displacement. - Fluid management - Record keeping - Choke operation - Pump operations - Strip/trip tank control - MCS monitors - Emergency preparedness - Gas monitoring - Control of work - Communication - Assignment of roles List the procedures to mitigate in the event of losses; - stop, monitor, try to slow kill rate - slow down/normal well control - volumetric method if losses continue - until influx is above shoe - volumetric

Y

Y

5

5

Y

Y

4

5

Y

Y

5

5



L ev eve l 3


Standard



L ev eve l 4

ImportanceTheory

CONTINGENCY PLANNING RECOGNITION OF PROBLEMS AND FIRST ACTIONS N01.01 N01.01 M01.00 M01.00 To be be able able to anal analyse yse the the down downhol hole e or surf surfac ace e proble problems ms that that migh mightt arise arise during well control operations.

PRESSURE GAUGE FAILURE N02.01 N02.01 M07.01 M07.01 To know know how how to dete detect ct when when gauge gaugess are are malfun malfuncti ctioni oning ng and and what what action actionss to take.

MUD/GAS SEPARATORS N03.01 N03.01 M08.02 M08.02 To know know what what corre correcti ctive ve acti action on to to take take when when operat operating ing limits limits are are being being reached or have been reached.

BOP FAILURE N04.01 N04.01 M09.01 M09.01

Given a completed kick sheet with pressure and instrument readings, analyse what may be happening during a well kill and identify the appropriate action; - plugged nozzles - string washout - blockage downhole - plugged or washed out choke - surface equipment failure - pump, hose washout - failure to maintain critical parameters

Y

N/A

5

N

Y

N/A

3

Y

Y

2

3

Y

Y

5

5

N

Y

N/A

3

N

Y

N/A

5

Recognise gauge malfunctions and the appropriate actions to take.

Describe the corrective action that should be taken before and when the mudseal is lost.

To know know how how to iden identif tify y and and respon respond d to BOP BOP failur failures es (suc (such h as leaka leakage' ge'ss at/of at/of a Given equipment, well and kick data, list the possible BOP failures and flange connection, weep-hole, ram packer, annular preventer e lement, demonstrate or indicate the ability to respond adequately and rapidly, e.g. by hydraulic leakage). closing a preventer below the failing BOP in question.

HYDRATE FORMATION N05.01 N05.01 M11.01 M11.01 To unde underst rstand and what what hydr hydrate atess are, are, the cond conditi itions ons like likely ly to lead lead to their their formation, and the main methods of hydrate prevention and removal.

N

Define hydrates. List the conditions likely to lead to their formation. List the main methods of hydrate prevention. List the main methods of removal.

LOST CIRCULATION N 06 06 .0 .0 1

T o u nd nd er er st st an an d t he he ac ac titi on on s t o b e t ak ak en en in in th th e e ve ve nt nt of of a lo lo ss ss of of re re ttu u rn rn s d ur ur in in g a From examples of minor to major losses, determine the correct initial action well control event and their operational limitations. to take in the case of a given event.



L ev eve l 3


Standard



L ev eve l 4

ImportanceTheory

CONTINGENCY PLANNING MAXIMUM PRESSURES N07.01 N07.01

J01.0 J01.06 6

To know know how to asse assess ss the the well well bore bore condi conditio tions ns ifif MAASP MAASP is appr approac oached hed and understand the consequences and appropriate actions.

Identify the hazards when annulus pressures are approaching MAASP and describe possible actions.

Y

Y

1

10

N

Y

N/A

5

KILL OR CHOKE LINE PROBLEMS

SSN08.01 SSN08.01

SM02.01 SM02.01 To know know how to to identify identify a problem problem in the choke line or kill line line according according to observed changes in drill pipe and casing pressure on a subsea BOP stack installation.

Given well and kick data, identify problems in the choke line or kill line according to observed changes in drill pipe and casing pressure.


L ev eve l 3



Standard



L ev eve l 4

ImportanceTheory

WELL CONTROL EQUIPMENT BLOWOUT PREVENTERS BOP STACK CONFIGURATION EQA01.01 EQA01.01 A01.01 A01.01 To unders understand tand BOP configura configuration tion and the well control control operations operations can be carried out.

EQA0 EQA01. 1.02 02

A01. A01.03 03

Given a stack and choke manifold configuration together with a list of possible operations, recognise which can, or cannot, be carried out.

To unde unders rsta tand nd the the over overal alll pres pressu sure re rati rating ng of a BOP BOP stac stack. k.

Anal Analys yse e the the BOP BOP stac stack k rati rating ng acco accord rdin ing g to the the diff differ eren entt comp compon onen ents ts and and thei theirr rated working pressures.

To understand understand the function function and configurat configuration ion of the Marine Riser, Riser, Lower Marine Riser Package (LMRP) and subsea BOP.

From a diagram, identify the function of the main components of the Marine Riser, LMRP and subsea BOP and to understand which well control operations for given configurations.

Y

Y

4

4

Y

Y

4

4

Y

Y

3

4

Y

Y

4

5

Y

Y

2

5

MARINE RISER

SSEQA01. SSEQA01.03 03 SA01.01 SA01.01

RAM TYPE REVENTERS EQA0 EQA02. 2.01 01 A02. A02.03 03 To know know the the oper operat atin ing g pri princ ncip iple less of of BOP BOP ram ram typ type e equi equipm pmen ent. t.

EQA02.02 EQA02.02

A02.04 A02.04

To know know when when the ram ram equipmen equipmentt must be changed changed for for specific specific operation. operation.

Give Given n dat data, a, anal analys yse e or desc descri ribe be ope opera rati ting ng prin princi cipl ples es of of BOP BOP ram ram typ type e equipment , including: - locking, - sealing, - hang off, - closing ratio, - direction of pressure, - wellbore assist, - different types, sizes, size of pipe, - stripping, inverted rams, - space out, - testing.

From a given BOP BOP configu configuratio ration, n, a descri description ption of the ongoing ongoing operati operations ons and and a description of the next operation, analyse which ram equipment has to be changed and why.



L ev eve l 3


Standard



L ev eve l 4

ImportanceTheory

BLOWOUT PREVENTERS BLIND/SHEAR RAM PERVENTERS EQA02 EQA02.01 .01 A03.0 A03.02 2 To unde underst rstand and the the opera operatin ting g princi principle pless of BOP BOP blind/ blind/she shear ar equip equipmen ment. t.

SSEQ SSEQA0 A02. 2.02 02 SA02 SA02.0 .01 1

To kno know w the the func functi tion onss and and oper operat atin ing g prin princi cipl ples es of of ram ram lock lockss

Descr Describe ibe the the opera operatin ting g princi principle pless under under the the follow following ing area areas; s; - forces, - effect of pipe types, - limitations (capabilities of shear rams, pipe, tool joint, wireline, low force shear rams, casing shear rams, shear test, pipe tension), - posting of instructions API STD 53 6.5.10.2.3

Y

Y

5

5

Desc Describ ribe e the the oper operat atin ing g prin princi cipl ples es of of ram ram lock lockss and and indi indica cate te whe when n and and how how ram ram locks are used.

Y

Y

3

4

D es es cr cr ib ib e t he he ca ca pa pa bi bi lili ti ti es es an an d l im im it it at at io io ns ns wi wi th th re re ga ga rrd d s t o o pe pe ra ra titi ng ng performance for different applications based on size of pipe, casing, no pipe, wireline, type of element etc.

Y

Y

5

5

D es es cr cri be be th th e i nd nd ic ica titi on on s o f fa ilil ur ur e a nd nd lili st st th th e co rr rr ec ect iv ive ac act io io ns ns to to be be ta ta ke ke n when it has failed.

N

Y

10

10

Y

Y

2

4

N

Y

N/A

5

N

Y

N/A

4

ANNULAR PREVENTERS E QA QA 0 03 3 .0 .0 1

T o u nd nd er er st st an an d t he he op op er er at at in in g p ri ri nc nc ip ip le le s o f a nn nn ul ul ar ar pr pr ev ev en en te te rs rs .

E QA QA 03 03. 02 02

A 04 04.0 2

To un un de de rs rs ta tan d ho w a nn nnu la lar pr pr ev ev en ent er ers ma may fa fa ilil .

EQA03.03 EQA03.03

A04.04 A04.04

To be be able to use use manufac manufacturer turer's 's data data and and well well bore bore pressur pressure e data data to select and adjust the correct closing pressure for a particular annular BOP.

From a given manufacturer's data and well-bore pressure, select the correct closing pressure and indicate how to proceed for adjustment.

To und under erst stan and d how how hydro hydrost stat atic ic pre press ssur ure e affe affect ctss annu annula larr prev preven ente ters rs..

Desc Describ ribe e how how the the foll follow owin ing g affe affect ct ann annul ular ar cap capab abil ilit itie iess and and the the meas measur ures es to to mitigate; - seawater hydrostatic - hydrostatic of the mud in the riser

SSEQ SSEQA0 A03. 3.04 04

SIDE OUTLET VALVES EQA0 EQA04. 4.01 01

To kno know w the the corr correc ectt loca locati tion onss for for remo remote tely ly ope opera rate ted d side side out outle lett valv valves es,, chec check k valves and other valves, and be able to state the pressure rating and correct hydraulic fluid operating pressures for a given hydraulically operated side outlet valve.

From a piping layout diagram, indicate the position of the manual and hydraulically operated side outlet valves and state why they are positioned that way.



L ev eve l 3


Standard



L ev eve l 4

ImportanceTheory

BLOWOUT PREVENTERS CONNECTIONS EQA05.01 EQA05.01

A00.01 A00.01

DIVERTERS E QA QA 06 06. 1

EQA0 EQA06. 6.02 02

SSEQA06. SSEQA06.03 03 SA03.01 SA03.01

Understan Understand d the the importa importance nce of correc correctt gasket gasket selection selection and make up procedures.

To be be ab ab le le to to de de sc scr ib ibe th th e p riri nc nci pl pl es es of of op op er era titi on on of of di di ve ve rt rt er er s. s.

From diagrams and descriptions identify the correct and incorrect make up of gaskets for specific types of connections.

L is is t wh en en di di ve ve rt rt er er s s ho ho ul ul d an d sh ou ou ld ld no no t b e u se se d. d. Identify key components and how they should be used and when e.g. large bore pipe, wind direction, purpose of locking mechanisms, top hole etc.

To unde unders rsta tand nd the the imp impli lica cati tion onss of gas gas rea reach chin ing g the the ris riser er (or (or comi coming ng out out of of solution) above the BOP and on the appropriate actions to take. Understand the consequences and risks involved in having the diverter system tied into the MGS.

State the correct course of action in a given situation.

To understand understand the operating operating mechanis mechanisms ms of common common types of diverters diverters used on floating operations.

From a specific layout, list the sequence of opening and closing the different elements and operating principles and how they should be effectively used; - shallow gas - potential gas in riser.

Y

Y

2

3

Y

Y

5

5

Y

Y

5

5

Y

Y

2

4



L ev eve l 3


Standard



L ev eve l 4

ImportanceTheory

ASSOCIATED WELL CONTROL EQUIPMENT INSIDE BOP'S AND KELLY COCKS EQB0 EQB01. 1.01 01

EQB01.02 EQB01.02

EQB01.03 EQB01.03

EQB01.04 EQB01.04

EQB01.05 EQB01.05

To unde unders rsta tand nd the the dif diffe fere rent nt type typess of of saf safety ety valv valves es and and their their func functi tion on..

A06.01 A06.01

A06.03 A06.03

A06.04 A06.04

A06.05 A06.05

Iden Identi tify fy the the diff differ eren entt typ types es of of val valve vess avai availa labl ble e and and thei theirr func functi tion on.. Y

N

5

N/A

Given specific information of tubular thread connections in use, identify compatibility with the Full Opening Drill Pipe Safety Valves (DPSV's) and inside BOPs and possible crossovers required to make up a connection.

Y

Y

5

5

From a schematic drawing or equipment information, describe operating principles and analyse use and installation. What they do, what they don't do and how they can fail.

Y

Y

2

4

To unders understand tand the advan advantages tages and disadvant disadvantages ages of of using using a float float valve valve in the string and consequences of failure.

Explain the advantages and disadvantages of using a float valve in the string and their impact on well control practices.

Y

Y

4

4

To unders understand tand the vario various us types types of of Drill Drill Pipe Pipe Safety Safety Valve Valve (DPSV) (DPSV) (also called called Kelly Cock and Lower Kelly Valve) as well as lower and upper full opening safety valves on Top Drive Systems and their limitations when shutting the well in off bottom.

Describe why they are needed, the sequence of shut in and the impact of DPSV on the top drive. Y

Y

3

4

To be be able to check check that that Full Full Open Open Drill Drill Pipe Pipe Safety Safety Valves Valves (DPSV's) (DPSV's) and inside inside BOPs have compatible thread connections with the tubulars in use.

To unders understand tand the operat operating ing princ principles iples and applicatio application n of the inside inside BOP BOP in use on the rig.



L ev eve l 3


Standard



L ev eve l 4

ImportanceTheory

CHOKE MANIFOLDS AND CHOKES ROUTING OF LINES EQC01.01 EQC01.01 C01.01 C01.01

To know know what alternativ alternative e circula circulating ting paths paths exist exist from from the pump pump through through the the choke manifold to the disposal system.

ADJUSTABLE AND FIXED CHOKES EQC02.01 EQC02.01 C02.01 C02.01 To unders understand tand the mechanica mechanicall operati operating ng princip principles les of of the the adjusta adjustable ble chokes chokes..

From a simple diagram of the piping system for the choke and standpipe manifold with valves, indicate possible valve status for a specific circulating path.

Y

N

4

N/A

Y

Y

1

2

Describe Describe operat operating ing principles principles and use.







L ev eve l 4

ImportanceTheory

AUXILIARY EQUIPMENT MUD/GAS SEPARATORS EQD01.01 EQD01.01 D01.02 D01.02 To know the the pressure pressure and flow operating operating limitati limitations ons of a Mud/Gas Mud/Gas Separator. Separator. From operatio operational nal data, data, calculate calculate at which which pressure pressure gas 'blow-thr 'blow-through' ough' occurs occurs.. Recognise the critical operating requirements.

VACUUM DEGASSER E QD QD 02 02.0 1 D 02 02. 01 01

To un un de de rs rs ta ta nd nd th the pu pur po pos e o f a Va Vac uu uu m D eg eg as as se se r. r.

N

Y

N/A

4

Y

Y

1

2

D es es cr cri be be th th e p ur ur po po se se of of Va Vacu um um D eg eg as as se se rs rs a nd nd w he he re re th th ey ey a re re us us ed ed .







L ev eve l 4

ImportanceTheory

BARRIERS BARRIER CONCEPT EQE01.01

To know what is meant by the term barrier.

Define what a barrier is.

E QE QE 01 01 .0 .0 2

T o u nd nd er er st st an an d t he he we we llll ba ba rrrr ie ie r e le le me me nt nt s i n d ri ri llll in in g o pe pe ra ra ti ti on on s. s.

I de de nt nt ifif y w ha ha t e le le me me nt nt s w ilil l f or or m a we we llll ba ba rrrr ie ie r e nv nv el el op op e d ur ur in in g d ri ri llll in in g. g.

EQE01.03

To kn know wh when we well ba barrier el eleme nt nts be be co come ac active .

From a diagram of of a well, se select th the el eleme nt nts th that fo form a barrier en envelope .

EQE0 EQE01. 1.04 04

EQE01.05

EQE01. EQE01.06 06

To unde unders rsta tand nd the the cri crite teri ria a for for acc accep epta tabl ble e pres pressu sure re tes testi ting ngss of mech mechan anic ical al barriers.

List the correct requirements of mechanical barrier testings.

To understand barrier test documentation.

Select the main requirements of a test document.

To unders understan tand d what what has to be be done done when when a well well barrie barrier/e r/elem lement ent test test fail fails. s.

Select Select the correc correctt actio action(s n(s)) to to take take on the test test fail failure ure of a well well barrier/element.

Y

Y

5

5

Y

Y

5

5

Y

Y

3

5

Y

Y

3

5

N

Y

N/A

3

Y

Y

3

5







L ev eve l 4

ImportanceTheory

TESTING BOP AND EQUIPMENT TESTING EQF01.01 EQF01.01 A08.01 A08.01 For a given BOP stack, stack, choke choke and kill manifo manifold ld config configurati uration, on, to be able to recognise correct and incorrect test procedures, and frequencies. In particular to know the correct actions to pressure test a valve or BOP function consistent with the direction of the well bore.

EQF0 EQF01. 1.02 02

EQF0 EQF01. 1.03 03

EQF01.04 EQF01.04

A08.02 A08.02

From a schematic of a BOP, Choke Manifold and Standpipe Manifold hook-up, indicate the valves to be opened or closed to perform a specific test, e.g. test of Blind/Shear Rams. To answer questions related to test frequency. Understand and identify the criteria for a successful pressure test.

N

Y

3

5

For For a give given n BOP BOP pres pressu sure re test test conf config igur urat atio ion n to to be be ena enabl ble e to to ens ensur ure e that that ther there e From given schematics of a pressure test configuration identify if there is an is an appropriate vent to atmosphere on the back side of the barrier to be appropriate vent on the back side of the barrier being tested and determine tested. Be able to determine the correct amount of fluid volume required for a the appropriate test volumes. given pressure test.

N

Y

N/A

5

Unde Unders rsta tand nd the the app appli lica cati tion on of an inve invert rted ed test test ram, ram, adva advant ntag ages es and and limitations (when used you do not test the WH connector).

From given schematics of a pressure test configuration identify which stack functions can be tested when using an inverted test ram.

N

Y

N/A

3

To unders understand tand the pressu pressure re test test requiremen requirements ts for for drill drill pipe pipe safety safety valves valves,, kelly kelly cocks and inside BOP's.

Describe the pressure test requirements for drill pipe safety valves, kelly-cocks and inside BOPs.

Y

Y

3

5

EQF01. EQF01.05 05

A08.0 A08.03 3

To know know the reco recomme mmende nded d BOP closin closing g press pressure uress and and closi closing ng times times..

From From manuf manufact acture urers rs BOP BOP equip equipmen mentt data data iden identif tify y corre correct ct clos closing ing pressu pressures res and times.

Y

Y

2

4

EQF01.06 EQF01.06

A08.04 A08.04

To understand understand pressure pressure ratings ratings for for equipment equipment used to test test blowout blowout prevention equipment.

From data provided calculate the rating of the equipment to be used in the test process and identify leak paths for both plugs and cup testers, and keep track of the volumes used.

Y

Y

2

4

To unde unders rsta tand nd the the fun funct ctio ion n tes testt and and freq freque uenc ncy y req requi uire reme ment ntss for for a giv given en BOP BOP and manifold arrangement.

From a given schematic/BOP arrangement identify the function test requirements for a given list.

Y

Y

2

4

INFLOW TESTING EQF02.01

To understand what an inflow test is.

Be able to define an inflow test.

EQF02.02

To understand the importance on an inflow test

Select the important reasons why an inflow test is carried out.

Y

Y

2

5

EQF0 EQF02. 2.03 03

To know know how how to to det deter ermi mine ne the the vol volum ume e and and pres pressu sure re chan changes ges that that take take plac place e during the test.

Create a dynamic and static graph / step up chart for the test. N

Y

N/A

5

To know know the the add addit itio iona nall act actio ions ns that that are are take taken n to to mit mitiga igate te the the kic kick k siz size e if if the the test should fail.

Recognise the indications that a negative pressure test has failed and explain the immediate course of action to be taken.

Y

Y

2

10

Unde Unders rsta tand nd the the pro proce cedu dure ress req requi uire red d to to und under erta take ke an effe effect ctiv ive e neg negat ativ ive e pressure test and the barriers tested.

Identify the appropriate steps for a negative pressure test and the line up required.

N

Y

N/A

5

Unde Unders rsta tand nd how how the the diff differ eren entt flu fluid id dens densit ities ies in the the well well will will affe affect ct interpretation of a negative pressure test.

Be able to map the different densities of fluids in the well and their impact. N

Y

N/A

5

EQF0 EQF02. 2.07 07

Unde Unders rsta tand nd the the spe speci cifi ficc rol roles es requ requir ired ed when when cond conduc ucti ting ng nega negati tive ve pres pressu sure re tests.

Identify the roles required when conducting negative pressure tests. N

Y

N/A

3

EQF0 EQF02. 2.08 08

Unde Unders rsta tand nd the the pot poten enti tial al leak leak path path that that coul could d occ occur ur duri during ng a neg negat ativ ive e pressure test.

From given data identify potential leak paths and appropriate actions. N

Y

N/A

3

EQF0 EQF01. 1.07 07

EQF0 EQF02. 2.04 04

EQF0 EQF02. 2.05 05

EQF0 EQF02. 2.06 06



L ev eve l 3


Standard



L ev eve l 4

ImportanceTheory

BOP CONTROL SYSTEMS EQG01.01 EQG01.01

EQG01.02 EQG01.02

EQG01 EQG01.03 .03

B01.02 B01.02

B02.01 B02.01

B03.0 B03.01 1

EQG01 EQG01.04 .04

EQG01.05 EQG01.05

To unders understand tand the general general operati operating ng princ principles iples of the the remote remote control control panel when drilling with a surface installed BOP.

To know know the the normal normal oper operati ating ng press pressure uress and/or and/or volu volumes mes in the the syste system m

To unde underst rstand and the purpos purpose e and and criter criteria ia for for an an accum accumula ulator tor draw draw down down test test..

B03.03 B03.03

EQG0 EQG01. 1.06 06

EQG01.07 EQG01.07

To unders understand tand the general general operati operating ng princ principles iples of the the BOP BOP Contro Controll System. System.

B03.04 B03.04

Describe Describe the the operat operating ing princi principles ples of a BOP Contro Controll System. System.

From a diagram or description, identify and describe the operating principles of the remote control panel.

Descr Describe ibe the the normal normal oper operati ating ng press pressure uress and/or and/or volu volumes mes for for all circ circuit uitss in the control system.

Y

3

5

Y

Y

5

5

Y

Y

5

5

N

Y

N/A

4

N

Y

N/A

4

Y

Y

10

10

Y

Y

4

4

From From a full full set set of data data descr describe ibe pass pass and fail fail crite criteria ria for an acc accumu umulat lator or draw draw down test.

To unders understand tand the sequence sequence of of events events that take place place between between operating operating the Driller’s Panel and a BOP opening or closing.

Be able to analyse the sequence of events and processes occurring when the stack is operated.

To unde unders rsta tand nd the the crit criter eria ia and and info inform rmat atio ion n ava avail ilab able le to to con confi firm rm wheth whether er or or not a specific function has successfully operated.

From a given list, identify the indications that show that a given function has successfully occurred or not.

To be be able to diagnos diagnose e simple simple function functional al problem problemss during during Stack Stack operation operation

Y

Given a set of symptom symptoms, s, identif identify y the likely cause cause of a malfunctio malfunction n and state the possible remedial or alternative actions that can be carried out.





SUBSEA BOP CONTROL SYSTEMS SSEQG01. SSEQG01.08 08 SB01.01 SB01.01 To know the general general operating operating principles principles of the BOP hydraulic hydraulic control control system system when drilling with a subsea BOP installed. SSEQG01. SSEQG01.09 09 SB01.03 SB01.03

SSEQG01. SSEQG01.10 10 SB01.06 SB01.06

SSEQG0 SSEQG01.1 1.11 1

SSEQ SSEQG0 G01. 1.12 12

SSEQG01. SSEQG01.13 13 SB01.07 SB01.07

SSEQ SSEQG0 G01. 1.14 14

To know the general general operating operating principles principles of the subsea subsea pods and the basic basic differences and requirements for hydraulic and MUX systems.



L ev eve l 4

ImportanceTheory

From a diagram or description, identify and describe the operating principles.

From a diagram or description, identify and describe the operating principles of a BOP control system; - Pods, - SPM's, - shuttle valves

To understand understand the principle principle of redundancy redundancy relating relating to subsea subsea control systems systems (e.g. pods).

Describe the principle of redundancy and identify back-up equipment for subsea control systems.

To unders understan tand d the the genera generall oper operati ating ng princip principles les of the remote remote contro controll pane panell when drilling with a subsea installed BOP.

From a diagram or description, identify and describe the operating principles of the remote control panel. How to operate, how to ensure it has worked and the actions to take if failure occurs.

Unde Unders rsta tand nd the the purpo purpose se of of havin having g subse subsea a moun mounte ted d accum accumul ulat ator or bott bottle less and the reason for increasing precharge pressure for a subsea bottle.

Explain the purpose and advantages of having the bottles at the BOP.

To know and understand understand the emergen emergency cy devices installe installed d on the BOP stack, both acoustic systems and ROV.

Explain the capabilities of the emergency devices and when they would be used.

To und under erst stan and d the the gener general al purp purpos ose e and and seque sequenc nce e of emer emerge genc ncy y disco disconn nnec ectt Describe the purpose and functionality of the auto shear system and dead man procedures (shearables and non shearables) including general identification of of system and when they should be used. colour convention for traffic light on dynamically positioned (DP) rigs.

Y

Y

1

4

Y

Y

1

3

Y

Y

1

3

Y

Y

5

5

Y

Y

1

3

Y

Y

1

2

Y

y

2

5

Drilling Levels 3 and 4 Syllabus

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