TRAINING REPORT AT

THE WELL

TEOTLECO 02

8 ½” STAGE

BY

ING EDGAR FERNAN ESPINOSA

CAZARIN

PEMEX ALIANZ II

PREPARED FOR

ING NATI JIMENEZ

ING MONSERRAT HERNANDEZ

2

Content

................................................................................................................................ 1

Introduction.............................................................................................................. 3

Scope ................................................................................................................... 3

Report Description ............................................................................................... 3

Mechanical state .................................................................................................. 4

Well Casing .......................................................................................................... 4

Drill String, Bit and Bottom Hole Assembly (BHA)................................................ 4

Annulus volume ................................................................................................... 5

Mud Pumps .......................................................................................................... 5

Mud Pits ............................................................................................................... 6

Reserves Tanks ................................................................................................... 6

Solid Control Equipment (SCE) ............................................................................ 7

Wellbore Antecedents ............................................................................................. 7

Drilling Operation ..................................................................................................... 8

DFG Simulations ................................................................................................... 10

Logistic .................................................................................................................. 10

Fluid Test............................................................................................................... 11

Inventory................................................................................................................ 13

List of Products ...................................................................................................... 14

Health Safety and Environment (HSE) .................................................................. 15

Conclusions and Recommendations ..................................................................... 15

3

Introduction

Scope

I had the opportunity to be in the first stage of this well, in that stage a 17.5

inch bit size was used to drill the first stage. This well has a slim design for this

reason the third stage will be drilled with a PDC 8 1/2” bit. The formation that will

be drilled is almost one hundred percent of shale, in a high pressure zone; a lost

pressure problem should not exist while the mud weigh condition been maintained

according to the program, notwithstanding other problem could happened as a

stuck pipe due to the well angle. Now I should take part of the operation, and give

my recommendations about mud treatment and also I should realize hydraulic

simulations in order to reach a good hole clean and maintain the mud in excellent

conditions

Report Description

The report will be present in the following form:

1. Those thinks that you should know at the first day at the Well:

Mechanical State

Mud Pits Capability

Revers Tanks Capability

Mud Mixing Equipment

Mud System

2. .Operations at the Well.

Well antecedents

Drilling Operations

Electrical Register

Cementing

3. Mud Engineer Roles

Logistic

Mud Test

Inventory

List of products

HSE

Conclusions and Recommendations

4

Mechanical state

Well Casing

In the table below appear the casing properties.

Type OD (in)

Weight (lbm/ft)

ID (in)

Shoe MD (ft)

Shoe TVD (ft)

Conductor Casing 20 129.33 18.750 164.05 164.05

Intermediate Casing 13.375 54.50 12.615 3281 3281

Conductor Casing 9.625 53.50 8.535 10335.15 10335.15

The well capacity in the casing and the open hole is in (lbb):

2 28.535 10335.15 8.5 1

825.8810

341.929

102 29 9lbb

Drill String, Bit and Bottom Hole Assembly (BHA)

The principal characteristical of drill string used in this stage were the

directional tools, all of these tools are very sophisticated and the mud should be in

good conditions with respect to the low solid rate concentration, according with the

mud weight used. Also the Solid control equipment might work in excellent

conditions due to the formations solid could damage the directional tools. A long

this stage the Well direction was built using the LWD and the mud motor, and the

bit used was a PDC bit.

Component Data Item #

Description OD (In)

ID (In)

Weight (lb/ft)

Top Connect

Serial Length (m)

Cumulative Length (m)

1 PDC Bit 8.5 3 230 P6-5/8”

REG 11806241 0.32 0.32

1 Mud

Motor 6 ½ 5.25 123.16

B6 5/8 REG

10469969 9.16 9.48

1 Stabilizer B6 5/8 REG

1 Pony

collar 8” 8 2.75 147.22

B6 5/8 REG

11460380 3.05 6.28

1 Stabilizer

8”x12” 8 2.8 150.13

B6 5/8 REG

11673574 2.68 15.01

1 Double

Pin 8 3.25 143.03

B6 5/8 REG

10469593 0.41 15.42

5

1

EWR-collar 8

(resistivity)

8 2 151 B6 5/8 REG

10469593 3.69 19.11

1

DGR Collar

(Gamma Ray)

8 2 142.7 - 285841 1.37 20.48

1 HCMI

Collar 8 (battery)

8 2 149.9 - 10909619 1.45 21.93

1 TM/DM Collar

8 3 147.22 B6 5/8 REG

10688002 4.6 26.53

1 CPV 7.875 3.25 137.72 B6 5/8 REG

SSFS-8014

0.74 27.27

5 Drill

Collar 8 2.25 157.4

6 5/8 REG

PEMEX 9.156 73.05

1 Sledgehammer 8”

8.125 2.75 132.58 6 5/8 REG

11652864 6.56 79.61

1 Combinat

ion 5 2.875 44.79

6 5/8 REG

PEMEX 9.52 81.99

12 DP HW

5” NC 50 5 3 53.6 NC 50 PEMEX 9.53 196.54

Length Total

196.54

The bit data appear in the next table

Bit Data

Bit Size (in) 8.5 Nozzles 6X20/32

Manufacturer HDBS FTA 1.841

Model FX65

Annulus volume

The volume in the annulus is in (lbb):

2 2 2 25 58.535 10335.15 8.5 134

542.181029 10

1.929

29lbb

Mud Pumps

At this well there are two triplex pumps, the piston on a triplex mud pump

work only on the forward stroke and generally short strokes.

6

Mud Pump

Pump Liner Diameter (in)

Length Liner (in)

Adjust pressure (psi

Model Type

Mud pump 1 6.5 14 4500 LEWCO 2214

TRIPLEX

Mud Pump 2 6.5 14 4500 National 14-P-220

TRIPLEX

The volume displacement for each pump is

26 12 0.95

  1  0.1365 4116

mud pump lbb stk

Both pumps has the same configurations, and displacement the same volume

Mud Pits

In the Table below appear the mud pits and its capacity

Mud Pits

Pit Names Factor Max Capacity (lbb)

Minimum Capacity (lbb)

Suction Pit 0.165 166 75.47

Pill Pit 0.058 58.36 25.15

Mix Pit 0.274 275.47 50.31

Settling pit 0.203 254.6 -

Sand Trap - 94.3 -

The maximum volume in all the pits is 135 m3, is very important to know and be

care full with the mud moves among the pits if doesn´t have control of the volumes

could occurred a spill.

Reserves Tanks

The capacity of the reserves tanks is show in the next table

Reserve Tanks

Name Capacity (lbb) Material Supplier

Vertical Tank N° 1 50 Control Fluid HALLIBURTON

Elevate Tank 18 Light Fluid PEMEX

Silo N° 1 45 Barite HALLIBURTON

Silo N° 2 45 Barite HALLIBURTON

Silo N °2 45 Barite HALLIBURTON

7

Solid Control Equipment (SCE)

The Solid control is one of the most important aspects of mud System

control, since it has a direct bearing on drilling efficiency.

Solid Control Equipment

Style Equipment Centrifuge Alfa laval 1458 Centrifuge Alfa laval 1458 Shaker D-285 Shaker D-285 Shaker D-285 Mud Cleaner -

The flow used with this bit size is just 430 gpm, for that reason just was used two

shakers during this stage. The rest of the equipment was used only in special case,

when the mud weight was increased, situation that occurred in few times

Type of screens for each shaker used for this drilling stay

Type of mesh used along the stage

Day Interval Type of screen

04-01-13 3559-3497 120-120-100-80

05-01-13 3618-3559 120-120-100-80

06-01-13 3638-3618 120-120-140-170

08-01-13 3691-3638 120-120-140-170

09-01-13 3745-3691 120-120-140-170

10-01-13 3770-3745 120-120-140-170

16-01-13 3818-3770 120-120-140-170

17-01-13 3915-3818 120-120-140-170

18-01-13 3988-3915 120-120-140-170

19-01-13 4076-3988 120-120-140-170

20-01-13 4158-4076 120-120-140-170

21-01-13 4281-4158 120-120-140-170

22-01-13 4324-4281 120-120-140-170

Different arrays were used thought the stage, because the mud weight was

increasing according the deep.

Wellbore Antecedents

This well is located in the Teotleco field; the last well drilled by BAROID in

this field was the Teotleco 15. For the type of well design, this stage have been

drilled with 8.5 bit, the first stage was drilled with 17.5 in bit, and the second stage

was drilled with 12.25 in bit. In this stage the well angle was built with the

8

directional tools, (MWD and Mud motor), these tools send their signal through the

mud, for that reason the mud properties should be in adequate conditions, in order

to achieve a good signal and get more detailed results. This stage began in

10335.15 ft, and the footage when I came was 1138.5 ft, the stage just had seven

days.

Drilling Operation

Between slide drilled meter and rotate drilled the drilling operations was in

normal conditions. While the angle was build the ROP was less due to the drilling

was in slide form, in average 30 minutes per meter, otherwise when the meters

were with rotate the ROP was in average 5 minutes. These highs ROP needed a

good hole cleaned.

Following the process PM-MXS-HAL-BDF-400 for the execution of the service

order, the parameters that might be follow while the drilling operations are the

density, the mud pit volume, and the viscosity. Each 30 minutes these parameters

are measured. Any variations in the volume should be notified to the driller. This

could be indications of a loss circulation or a blowout.

The drilling parameters appear in the table below.

Drilling Parameters

Day Drilled meters

ROP m/h

Volume in the hole (m3)

Interval Volumen loss in SCE (m3)

Formation

04/01 62 8.5 2.26 3559 - 3497 5.94 100% Shale

05/01 59 12.1 2.15 3618 - 3559 6.98 100 % Shale

06/01 20 6.6 0.73 3638 - 3618 2 100% Shale

08/01 53 9.2 1.94 3691- 3638 10.54 100% Shale

09/01 55 7.4 12.2 3745 - 3691 11.20 10% Mud stone 90%

Shale

10/12 25 4.8 0.91 3770 - 3745 3 100% Shale

16/01 48 13.1 1.75 3818 - 3770 3.72 100% shale

17/01 97 13.3 3.55 3915 - 3818 9.66 100% shale

18/01 73 10 2.67 3988 - 3915 8.41 100% shale

19/01 88 12 3.22 4076 - 3988 7.77 100% shale

20/01 82 15.8 3.00 4158 - 4076 4 100 % shale

21/01 123 20.2 4.50 4281 - 4158 3.75 100% shale

22/01 43 15.7 1.57 4324 - 4281 0.96 100% shale

26/01 17 11.2 0.62 4341 - 4324 1.28 100% shale

28/01 8 26.2 0.29 4349 - 4341 0.50 100% shale

9

29/01 83 11.3 3.03 4432- 4349 4.58 100% shale

During the first drilling days, 273 meters were drilled, with good ROP and keeping

the angle and the course, drilling in slide form using the mud motor. But the well

angle according to the plan was 41 degree, in order to get a better angle

construction, and safety operations, the Kelly system was replaced by a TOP-

DRIVE system, this change took six day including the out trip and the in trip. Before

trip out started a viscous pill was pump for clean the entire hole. The high viscosity

pill helped to sweep all the cuttings deposited in the annulus and avoid a

resistance along the trip out.

As the table shows with the after the TOP DRIVE was installed, the ROP increase

almost in two times. But the cuttings load was higher that the Kelly.

The formation drilled is a high pressure zone. One characteristic of these fields is

the high rotary torque even rotary stopped, and drags through the trips. For this

reason a high density program was designed to reach a high ROP and avoid

problems. The density program is showed in the table below:

Fluid Density Program

Deep (m) Density (gr)

3150 1.95

3550 1.96

4000 1.97

4100 1.98

4200 1.99

4300 2.00

4400 2.01

4500 2.02

4600 2.03

4675 2.04

4750 2.05

5670 2.05

The density program was followed until 4281 m deep, where a pack pipe almost

occurred, with this event was decided increase the density in two points until 2.01

gr/cc. the other modifications in the program was at 4047 during the trip in, other

drag was observed and the program was changed one more time, the density was

raised one point until 2.02 gr/cc.

10

The problems with the directional tools make lost much time with tripping for check

the tools signals.

DFG Simulations

A long the Drilling the ECD was predicted using the DFG simulator. Also the

hole cleaned was simulated, and the maximum cuttings charge was simulated in

this software. Theses parameters are calculate while have been drilling.

As mud engineer we should give these recommendations to the driller in order to

avoid a lost circulation during the Run casing and during the cementing.

With the high weight has driven the ECD should be followed in order to avoid a lost

circulations of fracture the same. The fracture pressure is 2.23 gr/cc

Logistic

The logistic is very important, you should in contact with the supervisor and

him with the mud plant, in order to request the mud necessary due to the material o

some other thing than they should provide you. All off those requests are elaborate

with a format FO-MXS-HAL-BDF-200B-101

With the quantity of material used during this stage the logistic take a lot

importance. Also the Fluid requirements were more, this due to the volume

consumed during the stage are large, and the impregnation of the solid is a lot to.

An effective communication with the supervisor should be keep, in order to have de

adequate materials in time and form.

In this well one problem was that only has one vertical tanks, for this reason the

mud request

11

Fluid Test

The Fluid used during the stage was the INVERMUL system; INVERMUL

tight-emulsion systems provide high-temperature stability and tolerance to

contaminants. This system use high concentrations of emulsifiers and fluid-loss

agents for maximum emulsion stability and minimal filtrate loss.

The system presented a problem with the electrical stability, this is a factor very

important due to if this value is less than 700 V, could be a sign of have a weak

stability and the emulsion could break if a contamination occurred.

Firs to all is necessary establish what is the reason for the stability is too low? One

factor could be a contamination with water, or water-wet solids or even a high salt

concentration are factors that affect the electrical stability value.

To solve this problem all of those factors should be discard, the water relation was

kept in 85/15 or even 86/14, the water contain never was higher. The water-wet

solid was a problem due to the system was increased its weight adding barite,

(solids), a concentration of wettings should be kept. Finally the concentration of

emulsifier was low according to the laboratory analysis realize by the tech support.

The concentration recommended by the lab tech, was a 5 l/m3 of emulsifier per 5

l/m3 of wetting, and 5 kg/m3 of Lyme. According with the pilot tests the electrical

stability should reach values closer of 1200 V, enough high for ensure a stable

emulsion.

The total system circulation was 250 m3 the concentrations used to solve this

problem were:

( ) ( ⁄ ) (

)

The same calculus was realized to get the quantity of wetting used, and the

quantities of lime used.

With the addition of these concentrations the problem was solved, furthermore the

temperature along the drilling helped to improve this parameter.

The other parameter that was adjusted was the salinity, this due to the behavior of

the formation.

The concentration of cacl2 should be raised until 295000ppm according to the

hydrometer test.

12

( )

( ) ( )( )( )

( )( )( )

Desired weight % CaCl2: D%CaCl2

%purity CaCl2 %purity

CaCl2 (lb/bbl whole mud) to add=

[

]

[

] ( )( )

(

⁄) ⁄ ( ) (

)

In the table below appears the parameters in the minimum and maximum mud

weight used during the drilling

Fluid Test

Parameters Miminum Maximum

Density (gr/cc) 1.95 2.02

Funnel Viscosity (s) 78 82

Filtered (cc) 2.2 2.4

Filter Cake (mm) 1 1

Gels (lb/100 ft2) 18/29 24/35

Salinity 260000 295,000

% Solid 37 38

%Oil 53 52

%water 9 9

R O/W 85/15 85/15

Plastic Viscosity (cp)

48 51

Yield Point (lb/100 ft2) 29 31

Electrical stability (volts) 435 978

13

Lyme excess (Kg/m3) 19.21 20.32

Alkalinity (ml) 5.3 5.5

600/300 125/77 133/82

200/100 56/37 61/43

6/3 18/16 21/20

Inventory

One of the most important aspects of any business is inventory

management and the Drilling Fluid is not the exception, for that reason we should

keep ours inventory update every day, and have a perfect control about the

products that were using along the stage.

The List Below contain the product used during my period in this well, each

material is used according to the analysis that was realized to the mud, and in

order to hold the properties according to the target´s parameters

Inventory

Product Unit Begin received Sent Used Final

Barite 1 Tonne 128 86 99 115

BAROFIBRE COARSE

40 lbm bag

74 74

Calcium carbonate coarse (M100)

25 kg Bag

280 70 210

Calcium carbonate medium (M200)

25 kg Bag

105 140 35 210

CALCIUM CHLORIDE PEL

25 KG Bag

100 70 70 100

DURATONE 50 lbm Bag

75 50 25 100

EZ MUL 55 Gal Drum

6 16 14 8

INVERMUL NT 55 Gal Drum

8 12

LIME HYDRATED

25 Kg Bag

140 200 212 128

GELTONE V 55 Gal DRUM

57 25 2 30

STEALSEAL 400

50 kg Bag

122 122

14

List of Products

The list below contains the Baroid´s product used during the stay, with these

products an adequate treatment was given to the system

List Product

Product Name Function Description

BAROFIBRE COARSE Sweeping agent is a synthetic fiber and is suitable for use in all fluid types, vertical and horizontal wells, and is an ideal product for use during milling operations

DURATONE-HT Filtration control agent is a modified lignitic product which is the primary filtration control additive for INVERMUL. reduce HTHP Filtrate at temperatures reaching 500°F

EZ MUL Wetting agent Emulsifier is the primary emulsifier and oil-wetting agent for application in INTEGRADE® drilling fluid systems. When FORTI-MUL emulsifier is used with RHEMOD™ L viscosifier and ADAPTA® filtrate reducer, it aids in producing a stable invert emulsion system with low filtration rates

INVERMUL Emulsifier Primary emulsifier is designed for mineral oil and paraffin based drilling fluid systems. emulsifier helps stabilize emulsions, aid suspension properties, and reduce HPHT filtration

STEAL SEAL (100 AND 200)

Bridging Agent lost circulation material products are resilient, angular, dual-carbon based lost circulation materials. These unique

15

resilient graphitic carbon (RGC) products allow tightly packed particles, under compression in pores and micro fractures, to compress and then expand without being dislodged by changes in differential pressure.

Health Safety and Environment (HSE)

Each week a Health Safety and Environment tour is realized, identifying the

problems related with the safety problems. This part is as important as the same

operation, or even more. Baroid has a different process to spread towards us, and

our customers the HSE policies.

The different Formats elaborated to spread our HSE policies are:

FO-MXS-HAL-BDF-400D Security meeting

FO-MXS-HAL-BDF-400H Safety Tours

FO-MXS-HAL-BDF-231A check list charge an discharge

Additionally the AST format is elaborate to comply with PEMEX policies.

Conclusions and Recommendations

Through this stage the angle was buit, with it, the drilling operation was slowly, due

to much of the meters were slides, and per each slide meter the ROP raised until

45 minutes per meter drilled. A 47 angle was built by the directional operators,

using the mud motor and its directional tools.

The troubles relationship with the mud was the mentioned in along this report, the

stability problem, and in some drilling days, the pass of cuttings through the control

solid equipment, situation that was followed with the SCE operators. The

concentration of drilled solid always was in conditions, but the addition of barite

also was a factor for raise this parameter.

The addition of emulsifier in conjunction with wetting and lime help to stabilize the

emulsion. The concentration used was almost two time bigger that the lab tech, but

the fluid received had a low concentration of emulsifier and wetting, for that reason

should increase this concentration.

16

One problem maybe was the concentration of organophilic clays used for the mud

plant, due to this material usually has a better reaction when has contact with high

temperatures. My recommendation is request a mud with light rheological

parameters, in order to avoid high plastic viscosities when this material has a

reaction with the high temperatures in the wellbore.