Drilling Program

Made by: E. Castillo. DRILLINGMade by: K. Tobar. PROGRAM.Reviewed by: Castillo-Tobar Well Ver. 1.0 Pag. 1 to 30 Approved by: Gabriela Morales. Published: September 8, 2015

ESPOLTech Petroleum

Corporation.

Castillo-Tobar Vertical Well

Drilling Program.

Operating Company: ESPOLTech Petroleum Corporation.

Well name: Castillo-Tobar Vertical Well.

Rig: Rig-2015

Oilfield: Gustavo Galindo Oilfield.

Date: September, 2015.

Made by:Erika Castillo.

Petroleum Engineering Student.

Asset Team Manager.

Made by:Kevin Tobar.

Petroleum Engineering Student.

Asset Team Manager

Approved by:MSc. Gabriela Morales.

Petroleum Engineering Master.

1

Made by: E. Castillo. DRILLINGMade by: K. Tobar. PROGRAM.Reviewed by: Castillo-Tobar Well Ver. 1.0 Pag.Approved by: Gabriela Morales. Published: Ago 27, 2015

Distribution list.

Name Company.

Erika Lisseth Castillo Castillo. ESPOLTech Petroleum Company.

Kevin Benjamín Tobar Mercado. ESPOLTech Petroleum Company.

Engineer A. Mud Petroleum Company Services.

Engineer B. Bit Petroleum Company Services.

Engineer C. Logging Petroleum Company Services.

Engineer D. Drilling Petroleum Company Services.

Auxiliary A1 Mud Petroleum Company Services.

Auxiliary C1 Logging Petroleum Company Services.

Auxiliary D1 Drilling Petroleum Company Services.



Mechanical Auxiliary. ESPOLTech Petroleum Company.Table 1- People who works in the drilling process. (Schlumberger) Modified by Erika Castillo, Kevin Tobar

Directory list.

Name Company Telephone.

Erika Lisseth Castillo Castillo. (Asset Team Manager)[email protected]

ESPOLTech Petroleum Company.

096 924 7756

Kevin Benjamín Tobar Mercado. (Asset Team Manager)[email protected]

ESPOLTech Petroleum Company.

099 650 9477

Engineer A. ( Mud Engineer)[email protected]

Mud Petroleum Company Services.

099 000 5555

Engineer B. ( Bit Engineer)[email protected]

Bit Petroleum Company Services.

099 777 4444

Engineer C. (Logging Engineer) [email protected]

Logging Petroleum Company Services.

099 111 2222

Engineer D. (Drilling Engineer)[email protected]

Drilling Petroleum Company Services.

099 333 8888

Auxiliary A1. (Petroleum Technologist)a1@ mudcompany.org.com

Mud Petroleum Company Services.

099 789 6789

Auxiliary C1. (Petroleum Technologist)c1@ loggingcompany.org.com

Logging Petroleum Company Services.

099 566 7676

Auxiliary D1. (Petroleum Technologist)d1@ drillingcompany.org.com


099 123 4567

Auxiliary D2. (Petroleum Technologist)D2@ drillingcompany.org.com


099 888 6767

Auxiliary D3. (Petroleum Technologist)D31@ drillingcompany.org.com


099 787 6789

Mechanical Auxiliary. (Mechanic) ESPOLTech Petroleum 099 555 5555

2


[email protected] Company.Table 2- Information about people who works in the drilling program (Schlumberger). Modified by Erika Castillo, Kevin Tobar

Organizational Chart.

Table 3- Description about the functions for each person in the drilling process. (Erika Castillo, 2015)

3

Kevin Benjamín Tobar Mercado.Company Man

Erika Lisseth Castillo CastilloCompany Womman.Person who works to the operating company and he or she gives the rulers and orders to everybody in the field while the drilling is running.

Engineer A.Professional who modify the characteristics of drilling mud and he or she is responsable of every decisitions abouth the drilling mud for each formation.

Auxiliary A1Person who helps to Engineer A taking samples in the mud tank, taking the necesary data to control the characterists of the well.

Engineer B.Bit Engineer.Professional specialized in bits. He cares and manage all operations that envolved to the bits to be used for each section during drilling.

Engineer C.Logging Engineer.Professional who works with others professionals to bring some information abouth LWD, MWD, plots, chats, evaluations, and loggings like caliper, SP, density, porosity, gamma ray, so on.

Auxiliary C1Person who helps with some operations that the Engineer C require.

Engineer D.Drilling Engineer.Professional who aproved all operations abouth the well, he or she get every data of the others engineers to take desicions to drill the well.

Auxiliary D1workman who operate the drilling tools.

Auxiliary D2Person who suport to others auxiliaries with the drilling tools.

Auxiliary D3Person who helps with the lubrication of the drilling tool.


Content.1. CASTILLO-TOBAR WELL´S DRILLING PROGRAM...................................5

2. SECURITY, HEALTH AND ENVIRONMENT & QUALITY.........................5

3. GENERAL INFORMATION..........................................................................................7

3.1 INTRODUCTION...............................................................................................7

4. GEOLOGY..........................................................................................................................7

4.1 TOPS OF THE FORMATION...................................................................................8

5. DRILLING FLUIDS.........................................................................................................9

6. CASING DESIGNING..................................................................................................12

7. CEMENTING...................................................................................................................16

7.1 CEMENT TOPS.......................................................................................................16

7.2 CEMENTING DESIGNING..................................................................................17

7.2.1 Operational sequence Cementation/Revetment 13-3/8''.....17

7.2.2 Operational sequence Cementation/Revetment 9-5/8''........18

7.2.3 Production Liner Cementing 7"...........................................................18

8. WELL CONTROL...........................................................................................................18

8.1 Primary Well Control........................................................................................18

8.2 Secondary Well Control...................................................................................19

8.3 Tertiary well control.........................................................................................19

9. BHA DESIGNING..........................................................................................................20

10. CONCLUSION.............................................................................................................22

11. SUGGESTION..............................................................................................................22

12. REFERENCES..............................................................................................................22

4

Made by: E. Castillo. DRILLINGMade by: K. Tobar. PROGRAM.Reviewed by: Castillo-Tobar Well Ver. 1.0 Pag. Approved by: Gabriela Morales. Published: Ago 27, 2015

1. CASTILLO-TOBAR WELL´S DRILLING PROGRAM.

Castillo-Tobar Vertical Well.

Well :

Castillo-Tobar Date : September , 2015

First Goal :

Sandstone “T” lower Oilfield : Gustavo Galindo

Location :

“Castillo-Tobar V”

Cellar : “CT-15”

Estimated days :

25 days (Drilling) Rig : Rig-2015

Rev. 20" :

N/A RTE : 865.01’ relative @ MSL

Rev. 13 3/8" :

5320’ MD / TVD @ 0° RKB : 26' relative @ GL

Liner 7” :

8760’ MD / TVD @ 0°

Target : Circumference with a ratio de +/- 50 pies Table 4-General Information about Castillo-Tobar Vertical Well. (Schlumberger) Modified by Castillo, Tobar.

2. SECURITY, HEALTH AND ENVIRONMENT & QUALITY.

Security, Health and Environment.

Staff security, protection and care of the environment and equipment

is important.

When starting operations continue in the Loss Prevention Team (LPT)

with the participation of at least one representative from each

company in the project, which will meet at least once every seven

days to analyse and / or discuss issues regarding QHSE (Quality,

Health, Safety and Environment).

Improvement kits QHSE will be on location for use weekly.

Action plans will be assigned to staff people and these plans will must

do it.

Drills will be conducted according to the standards of well control. The

attention paid to these drills and response time should be reported in

the Open Wells and drill the IADC format.

Every critical operations that will be performed at the location, and

drill hole must be preceded by a meeting of security and operations

to identify the tasks and warnings during the execution of drilling.

5


The meeting areas for emergencies, should be clearly identified in the

location of Castillo-Tobar Well and the location of these areas must be

communicated to everybody who will work on location.

An instruction about Security, Health and Environment should be

given to everybody before starting work on location.

Carry out “The Substitute Regulation to the Environmental

Regulations for Hydrocarbon Operations in Ecuador".

Quality.

Inspect the rig before beginning drilling operations.

Before you begin drilling operations will be completed a checklist of

the oilfield, which must be signed by the Drilling Operations

Supervisor, Leader Directional Drilling and Drill Manager.

A checklist of equipment should be prepared before starting each

section of the well and should be communicated to staff offices.

Daily reports should be placing in the safety meetings held and the

topics will be discussed.

The Superintendent and Project Drilling Engineer must be called

immediately in case of injuries / accidents, well control, stuck pipe or

other significant problems related to drilling operations.

Every drilling parameters: Torque in / on the merits, weight lifting,

lowering and rotating, flow rate and pressure surface in / on the

bottom, will be monitored by the staff of the rig at each stop of pipe

and each section and they must be compared with the estimated

parameters. It is expected that the drill rig crew maintain surveillance

and / or monitoring of drilling parameters and react to the conditions

of the hole.

Monitoring / report daily operating hours of the hammers, MWD tools,

downhole motor, and the maximum speed of the roller-cone bits.

Inspect all components of the BHA before starting drilling operations.

The mud tanks must be in perfect working condition before you start

drilling. It is mandatory to fill in the sheet travel.

6


3. GENERAL INFORMATION.

3.1 INTRODUCTION.

The Castillo-Tobar Well was consider like a vertical producer well in

the Gustavo Galindo Oilfield. We have designed this well with 3 revetment

and we have selected to “Hollin Top” Sandstone like our producer zone.

The surface revetment is of 13 3/8" will be located at the top of

Orteguaza to the depth of 5320 feet. Then, an intermediate revetment

production of 9 5/8" is located on top of Basal Tena with a depth of

8,760pies. Finally, the area of interest will be covered using a liner 7

"located at 10,090 feet (Final Depth).

The main operational goals are:

To minimize formation damage by drilling through the reservoir

using a fluid with a density as low as possible, using a weighting

material like CaCO3 to avoid damages in the reservoirs, while there

are good techniques of drilling to avoid the paste differential in the

permeable sands and with high porosity of the Napo formation.

To evaluate areas of interest whit WL/LWD tools.

Running and cementing production liner 7” according the laws

given by the Ministry of Hydrocarbons.

4. GEOLOGY.

The Gustavo Galindo Oilfield is located in Prosperina, 30.5 km

Perimetral Avenue, Guayaquil, Guayas, Ecuador.

7


Figure 1- Contour Map and Elevations of Gustavo Galindo Oilfield (Erika Castillo, 2015)

4.1 TOPS OF THE FORMATION.

Formation / Reservoir MD (ft) TVD (ft)

Top Orteguaza 5422.01 5422.01

Top Tiyuyacu Conglomerate Superior 6443.01 6443.01

Base Tiyuyacu Conglomerate Superior 6620.01 6620.01

Top Tiyuyacu Conglomerate lower 7382.01 7382.01

Top Tena 7923.01 7923.01

Top Basal Tena 8810.01 8810.01

Top Napo 8812.01 8812.01

Main Limestone M-1 9080.01 9080.01

Top Limestone M-2 9292.01 9292.01

Base Limestone M-2 9329.01 9329.01

8


Top Limestone A 9408.01 9408.01

Base Limestone A 9480.01 9480.01

Top U Superior 9515.01 9515.01

Top U Inferior 9550.01 9550.01

Base U Inferior 9603.01 9603.01

Top Limestone B 9685.01 9685.01

Top T Superior 9699.01 9699.01

Top T Inferior 9769.01 9769.01

Top Limestone C 9929.01 9929.01

Top Hollin Superior 9942.01 9942.01

Top Hollin Inferior 9966.01 9966.01 TD 10090.00 10090.00

Table 5- Description of the lithology (Schlumberger). Modified by Castillo, Tobar.

According with this reference (karolablue, 2013), a well is designed

from the bottom to the top because the data logging is generated in the

same form since the exploration analysis, that’s why with the information

expected from the geologic column of the neighbouring wells by seismic or

running logging tools in order to predetermine the existence of abnormal

formation pressures and temperatures and that may damage my drilling

tools. Finally, designing my well from the bottom to the top, I assure while I

´m drilling intermediate zones, the bottom hole will not be damaged due to

landslides.

5. DRILLING FLUIDS.

According to the reference (Loor, 2015) the drilling fluid or mud is a

citric component in the drilling process, whose main functions are to remove

cuttings downhole to surface and control the formation pressure. The mud

can be oil-based or water, and is a mixture of chemicals that give the fluid

properties to fulfil its function.

Drilling mud must have certain characteristics like non-toxicity, non-

corrosive, non-flammable, it must be inert to all pollutants such as soluble

salts to be attached to the system during the drilling process.

The main estimated to describe the drilling mud properties are: mud weight,

plastic viscosity, yield point, gel strengths and mud filtering.

9


The density of the drilling mud is one of the main parameters for drilling and

for calculating hydraulic; where the mud will gradually increase as drilling

deeper in order to control the formation pressure.

Remove cuttings downhole: Main function of the mud drilling that must

continually remove cuttings generated at the surface, which could reduce

the efficiency of the string. For this purpose the mud must be designed to:

• Transporting the cuts to surface while circulating.

• Suspend the courts while it is not circulating.

• Eject suspension cuts on the surface.

The mud properties can be modified to suit different downhole conditions:

Downhole conditions/ Function of drilling mud.

Properties can be modified.

Transporting cuts downhole to surface.

Yield point, apparent viscosity, velocity, gel strengths.

Prevent the influx of formation fluids into the well

Density of mud.

Maintain wellbore stability. Density, clay chemistry.

Cool and lubricate the drill bit.

Density and velocity.

Transmitting hydraulic horsepower to the drill.

Velocity, density y viscosity.

Table 6-Properties of the mud. (Loor, 2015) Modified by Castillo, Tobar.

Perhaps, we can drill wells in reservoirs with high pressures and

temperatures (more than 300 oF). Drilling with a high pressure in the well

can fracture the reservoir and it will get losses of mud by filtration.

However, high conditions about temperature can affect to our drill mud,

changing some characteristics like the viscosity and pressure gradient.

Finally, we know that water absorb warm, so not is recommendable drilling

with water-base mud for reservoirs with high temperature. In addition, it´s

recommendable to use oil-base mud for drilling this wells because the oil

can balance the characteristics that warm modify in the mud.

10


With this information, we can designed the drilling mud for each section in

the process:

SECTION

HOLE

REVETMENT DEPH

[ft]

LITHOLOGY MUD TYPE DENSITY

[ppg]

16 " Surface 13-3 / 8" 0 - 5.320 Indiferenciado –

Chalcana

Native fluid 8.4

12 1/4” Intermediate 9-

5/8”

5,720 –

9,423

Orteguaza –

Tiyuyacu -

Tena

Native fluid 12.5

8 1/2” Liner 7’’ 8,760 –

10,090

Basal Tena – Napo – Limestone – Sand “U”- Sand “T” - Hollín

Native fluid 9.2

Table 7- Drilling mud per section. (Erika Castillo, 2015)

In the above table, it is described for each section of the drilling sludge

type to be used and the respective density, but this density is not always

constant for the entire height of the formation due to the different pressures

to find along the process. Therefore, we introduce the term ECD to extend

the knowledge of the management of drilling mud.

The ECD is the effective density with drilling mud circulating through the

system while drilling. This density is the one that generates the actual

pressure of the drilling fluid on the formation being traversed. And this

equation is given by the sum of the normal mud density, under static

conditions, the ratio of the pressure drop in the bit and product depth 0.052.

Factors affecting the ECD are the main properties of the sludge which

must interact as directly affect the ECD way:

The plastic viscosity.

The yield point.

Gel strengths.

11


The less viscous is a drilling fluid will tend to reduce the ECD and gel

strengths from less because when the rotation is stopped during drilling

system becomes static, and you need to restart printing additional pressure

to circulating system and break the thixotropic of the mud.

They must balance, Petroleum Engineer cannot play much down mud

properties to improve ECD, taking into account the parameters using a

minimum to ensure hole cleaning and stability, then you have to design the

system so that there is a balance between a good ECD that will not damage

or fracture the formation and generate a good cleaning well ensuring

stability. The consequences of ECD are high formation damage that

can be generated by passing through formations of interest or charging

zones. Another consequence is fractured formations through the same that

can cause you to lost circulation and the liquid part of the mud from

escaping from the fracture, bone sludge is dewatered, and properties vary

therefore problems would have the entire system up cuts to surface,

overheating and Additional bit wear Last thing you want is that the sludge

has a fault as it is the blood of the well, when something is wrong with the

well, mud analysis are made. The ECD generates an additional hydrostatic

pressure which can crash and fracture the formation spanning pressure.

When this occurs, should be incorporated into polymer particles system

developed to weigh the mud but without increasing plastic viscosity and gel

efforts, but this only provides a small window in values, care should be

interacting with falling pressure at the bottom of the assembly line.

6. CASING DESIGNING.

To talk about casing designing we need to show you the mechanical

scheme of the well, the considerations about depths and the revetment for

each section.

12


Figure 2- Mechanical scheme Castillo-Tobar Vertical well (Schlumberger). Modified by Castillo, Tobar.

13

Hole 8 1/2” @ 10090 MD/10090 TVD

Inclination: 0 Deg.

Hole 12-1/4”@ 8760 MD/87600 TVD

Inclination: 0 Deg.

REVETMENT 9-5/8”

Rev 9-5/8” @ 8760´MD

Max. Inclination 0o @ 0´MDTOP Liner 7” @ 8640´MD

Rev 13-3/8” @ 5200´MD

Hole 16” @ 5200´MD/5200´TVD

Inclination: 0 Deg.

LINER 7”

REVETMENT 13-3/8”


To design a casing include some factors should be consider by the

drilling and cementing people, characteristics like: The pore and fracture

pressure.

The pore pressure is the pressure of the formation fluids from borehole

or fluid in the pores of a reservoir, and this pressure is important because it

is the required pressure in the well to balance the walls of the well, fluid

static drilling must have a pressure equal to the pore pressure at a given

depth.

The fracture pressure is the pressure required to induce fractures in a

rock at a given depth, is very important to know because with this gradient

will design our fluid simulate an ECD, that doesn’t cause the downhole

pressure exceeds the pressure fracture and avoid having lost circulation.

In theory, this is the density in pounds per gallon in the subsoil as depth

increases. The figure 3, begins at 8.33 on the horizontal axis gradient starts

from there, because that is the normal water density 8.33 pounds per gallon

From 4000 feet in depth, is a variation of the density to a depth about 4500

feet to 4000 feet before the normal pressure there, bone straight line, then

this curve indicates the onset of geo-pressures, after 4500 feet,

approximately to the depth of 4600 feet, seating the first casing, the surface

or 13 3/8 ". After that in the graph a normal pressure is observed up before

reaching the depth of 7000 feet, taking into account that in the very depths

between 6,000 feet and 7,000 feet there is a fractured zone which means

that you should have a sludge that controls loss of filtering fracture proof

material loss, or what is known in the world of drilling as LCM (Lost

circulation materials), that must be added to the sludge to prevent

dehydration, then another area until 8000 geo-pressures feet. Personally,

we would seat the casing about 100 feet after the geo-pressures, that is to

the depth of 8100 feet, until then the intermediate casing, thereafter hang

one liner 7 inches from 8100 feet to 10,000 feet deep because from there is

already the charging zone, we mean the reservoir and should be stable to

run and complete records after cementing the well hole.

14


Figure 3- graph (pore/fracture pressure) for the oil field, provided by (Morales, 2015)

15


7. CEMENTING.

The function of the cementing is to keep the casing attached to the shaft

wall on pressures prevent the formation into the well to avoid contamination

by freshwater aquifers.

The additives of the cementing help to control pH, for preventing the

reproduction of bacteria, to control the setting time, to increase or decrease

the viscosity.

Some casing strings are not cemented back to surface, the problem is

when the annular space is not fully cemented, the casing collapse or deform

and it can produce possible contamination of saturated water for human

consumption zones. In addition, the casing can be exposed to corrosion in

contact with corrosive fluids.

There are some cement´s type, like:

C. Type A and B: For cementing with little depth.

C. Type C: For cementing formations with high resistivity in a short

time.

C. Type D, E and F: Isn´t common.

C. Type G: It´s compatible with most additives, we can use this type

of cement for cementing formations with high pressure and

temperature. It´s the most common in our country.

7.1 CEMENT TOPS.

Casing Tail Lead Planned Excess

Slurry Top Slurry Top 13 3/8" 15.6 ppg

Type "A" 4820’ 13.5 ppg

Type "A" Superficial 0%

9 5/8" 15.8 ppg Type "G"

8260’ 13.5 ppg Type "G"

5200’ 10%

7" 16.4 ppg Type "G"

8940’ 13.8 ppg Type "G"

8700’ 20% over caliper

Table 8- Cement types and densities used per section. (Schlumberger) Modified by Castillo, Tobar.

To view better the information filled in the table we have added a figure

to represent the well´s scheme with the revetments and the cementation.

16


Figure 4- Representation of the Cement tops. (Schlumberger)

7.2 CEMENTING DESIGNING.

7.2.1 Operational sequence Cementation/Revetment 13-3/8''

A cementing program will be sent before the operation casing down,

with updated data and information hole laboratory tests, equipment and

tools to use which is approved for operations and engineering.

The cementing program has been designed using the following

characteristics: 500 feet provide insulation from the casing shoe 13-3 / 8 ''

using a grout line, cement type A 15.6 ppg, and 4820 feet above with grout

filler, type A 13.5 ppg.

Cementing the casing 13-3 / 8" and move the cement slurry using

drilling pumps. The Shoe track is composed by one seal coating 13-3 / 8 ''.

Therefore, if it should not seat the plug. It should move only half sub (50%)

of the volume of track shoe. Testing casing using 500 psi above the seating

pressure of the cap. After the cement must settle the casing 13 3/8 "deep.

17


7.2.2 Operational sequence Cementation/Revetment 9-5/8''

The cementing program is designed using the following criteria:

Provide insulation 500' from the casing shoe 9 5/8 " using a cement slurry

with 15.8 ppg of density, type G and isolate the rest of the casing with grout

filler, 13.5 ppg, type G and it will cover approximately 3040 feet. 70 bbl of

slurry cement type G is pumped, 10 bbl of water and 20bbl of mud and 620

bbl of mud for displacement of the tools.

7.2.3 Production Liner Cementing 7"

The liner cementing production is one of the most critical operations

and well life depends on the isolation obtained with the cement during this

operation. All efforts should be made to ensure the best conditions for the

cementing operation. It will be pumped, 20 bbl of slurry Scavenger (12.5

ppg of density), 30.9 bbl of slurry filling (13.8 ppg) and 81 bbl of slurry tail

(16.8 ppg) covering up to 50 feet below the top of the hanger.

The calculus made per each section were based in the following

equations Vol .anular=(Hole siz e2−External Diamete r2 )Deph

144 and

Vol . cement=Vol . anular+Vol .water+Vol . aditives

The information given in the previous paragraphs are numbers

estimated according to the investigation obtained of the thesis previous to

get the profession in Petroleum Engineering made by (Loor, 2015) and we

made an interview about ¿What will we do when you had finished

cementation operation and the CBL log had shown that is not a good bond?

The interviewee told us one of the techniques applied for this case.

To remedy a defective primary cementing exists the secondary

cementing or remedial cementing. It´s an additional process is made for

fixing pipeline leak, fixing a bad channelling of mud or cement sufficient

height in the annulus and help to remove the intrusion of water from above,

below or within in the oil producing zone.

18


8. WELL CONTROL.

8.1 Primary Well Control.

So the primary control is defined as the prevention of formation fluid

flow by maintaining a hydrostatic pressure equal to or greater than the

pressure of the formation fluids, but lower than the fracture pressure of the

formation. It is very important to make ensure that well control is preserved

at all times.

This includes:

Drilling fluids whit adequate density are used.

Active system volumes are continuously monitored.

Changes are detected immediately and correct actions are being

performed.

8.2 Secondary Well Control.

If the pressure of our drilling fluids fails to prevent formation fluid to

enter the wellbore, the well will flow. Though the use of a blowout

preventer, we can prevent the fluids from escaping the well.

8.3 Tertiary well control.

Induce an underground blowout to avoid the occurrence of an imminent

surface blowout. Afterward, apply special techniques and procedures to stop

the resulting subsurface cross flow and regain well control.

A kick is a problem that arises in the pressure control system is located

well inside the rock drilling pressure is greater than the hydrostatic acting

on the face of the well or rock. When this happens, the greater the

formation pressure has a tendency one force formation fluids into the well.

This forced fluid flow is called a kick. If the flow is controlled successfully, to

get you consider that he has been killed. An amazing wild pitch that rise in

intensity can cause what is known as a blowout.

Kicks generally occur as a result of formation pressure being greater

than mud hydrostatic pressure, which the causes fluids to flow from the

formation into the well. In almost all drilling operations, the operator

attempts to maintain a hydrostatic pressure greater than formation pressure

and, thus, prevent kicks; however, on occasion the formation will exceed the

19


mud pressure and a kick will occur. Reasons for this imbalance explain the

causes of kicks:

Insufficient mud weight.

Improper hole fill-up during trips.

Swabbing.

Cut mud.

Lost circulation.

9. BHA DESIGNING.

20


Figure 5- BHA Model (Schlumberger)

To make the calculation of WOB should do a little math operation to

estimate the weight that supported the bit. WOB = weight of each pipe x

pipe length + total weight of the BHA.

21


WOB = (21.87 lb / ft) x (1000ft) + (65 klbs), then the value of WOP

approximately 218.7 klbs from top to bottom (10,000 ft MD), assuming a

weight of 65 klbs by Heavy weight drill pipes, weight on bit (WOB) applied

in the last section, is generally less than 10% of the weight of the drill string,

because the bit does not hold as much weight as if you apply too much

weight, the BHA will sag and will start taking inclination and what we want is

to maintain the verticality of the well then you have to analyze the WOB to

apply in this section will be between 10 and 20 KLBS weight that will support

the bit of the total weight of the drill string. The BHA to be used should be a

basic BHA because a vertical pit is greater complications, such BHA should

be:

1) Drill PDC 8 1/2 " (This bit should be 6 and 6 nozzles fins with a TFA

between 0.5 and 0.6 , and an area of considerable cuts eviction ).

2) A motor with plain and simple shirt.

3) A substitute float, which is what will make the engine and gear to act as a

check valve so that there is no flow in reverse.

4) A stabilizer 8 3/8 "to give stability to the BHA packaging.

5) Monel pony or what is the same a short non-magnetic drill collar, to

prevent magnetic interference.

6) The MWD tool that will register well data of orientation, azimuth,

direction, inclination, coordinates.

7) A short Monel or drill collar.

8) Heavy weight drill pipe.

9) A hydraulic hammer to the drawbacks are as mechanical or differential.

10) More heavy drill pipe (HWDP).

11) Drill pipe and dill pipe.

All this will give verticality to the well, the BHA is heavy and vertical.

The production section , always drilling with drill PDC 6 fins is the best to

provide durability due to the abrasive lithology's, and has an area of good

22


eviction before the MWD tool, should go a " Monel pony" that is aa drill

strain nonmagnetic that do not interfere with the MWD, and after the MWD

must be another monel, across string, whatever, should go a " hydraulic jar"

I mean a hydraulic hammer when the string sticking , to stress and

hammering and recover the string, provided HWDP ( pipe heavy drilling ) is

used in the BHA, because it makes as pendulum effect, it gives weight to

maintain direction whole string must have a stabilizer or a set of them,

depending the purpose of the BHA .

10. CONCLUSION.

A drilling program is a document which register all information about

the well, is a document elaborated by the operating company annexing the

information given by the services companies. The services companies bring

information about bit selection, logging, mud logging, geology, drilling

fluids, cementing, casing designing, BHA designing, so on. The information

solved in this document is based in the descripted references and was

modified by us with the objective to bring a paper which to help to other

students in the petroleum career. Finally, learning to read a drilling program

means to learn everything about the well, the hole and the reservoir.

11. SUGGESTION.

Group work with accurate and verified information, know to analyze

data, use correctly the equations for making calculates, and manage the

content of the report and to respect the authors of their references.

12. REFERENCES.

Erika Castillo, K. T. (2015). Drilling Program Castillo-Tobar Vertical Well.

Guayaquil.

karolablue. (2013, febrero 28). slideshare. Retrieved from Diseño de la

perforación de pozos: http://es.slideshare.net/Karolablue/diseo-de-la-

perforacion-de-pozos

Loor, I. A. (2015, Agosto 28). Fluidos de Perforación. (K. T. Erika Castillo,

Interviewer)

23


Morales, G. (2015). Graph (Pore7Fracture Pressure). Guayaquil.

Schlumberger. (n.d.). Drilling Program YAN-West.

24

Drilling Program

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