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r ng p m za on o e ar on erous orma on
Using Automated Drilling Tools and Hybrid Bits
era. on erenc a ag s ra e a
SPE STUDENT CHAPTER COCHABAMBA
Gustavo Prraga / Paul Schulhauser Baker Hughes
Edwin Badani Repsol
,
June, 7th 2013
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Presentation outline
I. Introduction
.
III. Development
.
V. Conclusions
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Introduction Geographical LocationI.
415,000 420,000 425,000 430,000
7'685,000
7'690,000
7'685,000
7'690,000
HCY-X1
7'680,0007'680,000
7'675,0007'675,000
Ubicacin
Pozo MGR-6
MGR-4
Ubicacin
Pozo MGR-5
Field located in Southern Bolivia
7'670,000
7'665,000
7'670,000
7'665,000
MGR-X3
MGR-X1
- Carboniferous sequence poses the
greatest challenges
-
7'660,0007'660,000
MGR-X2415,000 420,000 425,000 430,000
7'655,0007'655,000
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Introduction Formation analysisI.
Carboniferous PeriodCarboniferous Period comprises:
San Telmo
(mudstone interbedded
with Diamictite, Sandstone and
Pelite)
Escarpment
(Las Peas)
(Sandstone interbedded with
Tarija
(Sandstone and Diamictite)
Itacuami (Pelite)
T bi Tupambi an s one n er e ewith Conglomerate and Pelite)
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Background History drillingII.
EscarpmentTarija I
Itacuami I
Taiguati
Tupambi I
Bororigua
FaultHCY-X1
TarijaEscarpment II
MGR-6
MGR-4
ItacuamiItacuami II
Escarpment III
MGR-X3
MGR-5
MGR-X1
Drilling time in HCY-X1 took 44 days longer to reach 3300m than
MGR-X4 (only 17 section)
Both sections drilling the same geologic sequence Escarpment
Taiguati Tarija Tupambi (2200m length)
Tupambi III
Itacuami IIIMGR-X2
Cost difference for using different systems:3.9M
(17 section)
Well closure in MGR-X4 = 50m @ 3294m
Well closure in HCY-X1 = 118m @ 3299m
MGR X4
Tarija II
HCY-X1 (RSS)MGR-4 (VTK)
MGR-X4
HCY-X1: 38 BIT RUNS TO REACH 3386m
2004 2006
17 Sections
UCS 0-30ksi
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Background ScenarioII.
Top issues to be focused on them for improvements
Geologyeology eologyeology
Examine formation properties andperform trials on Simulator
Drilling System Enhancement
Vibration Management
BHAHA
Hole tortuosity
Bit designitit
New cutting structure
Bit selection/optimization
Vibration Management
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Background ScenarioII.
BHAHA
DeviationBHA design influences on results:
ontro
Poor
Hole instability
Tortuosity
Performances Drilling time
Vibrations
Uneven wear on pads of RSS
Influenced by Off Center mechanism
DHM+RNBS DHM+STB SLEEVE
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Background ScenarioII.
Bitsits
Tracking, Off-Center and
Rounded Gage
considered as main dull
characteristics
st
impregnated bit and
turbine
Lost in Hole & Side
Track
(17 MGR-5)
17 PDC (HCY-X1)
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DevelopmentIII.
APerformanceerformance Drillingrilling Proposalroposal
, combining automated drilling systems
(Vertitrak/TruTrak) and hybrid bits (Kymera) is offered as the Best Solution for
.
Objectives to be achieved:
Keep verticality.
Improve hole quality.
Reduce tortuosity.
Reduce bit runs.
Increase ROP values.
.
Reduce torque and drag.
Maximum safety for the casing program.
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Genesis of Kymera designIII.
Roller Cone
as c u ng ec an cs
CRUSHING
PDC
Basic Cuttin Mechanics
SHE RING
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Kymera bit action on bottomIII.
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Automated Directional Drilling ToolsIII.
Movie created from experience in Northern Argentina (Mac-1001 vs. Mac-1001bis wells - PAE)
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Field Results Drilling curvesIV.
Daily curves
Remarkable resultsDistance drilled and ROP
si nificantl increased
3 Kymera bits (24)
for drilling 990m
Cut several days off
original drilling curves (not
shown)4 Kymera bits (17)
Improved last poor
experiences using previous
technologies (bits & drilling
s stems
6 Kymera bits
(17) for
drilling 1509.5m
for drilling 1321m
except
(169m of the section
length drilled with
other bit types)
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Field Results Drilling curves of 24-26IV.
3 Kymera bits for drilling 990m
(MGR-6)DHM
VTK
Considered as the Best Performance
through Carboniferous formation.
Greater distance drilled per bit
2 4X
VTK
2.4X
.
Improved ROP (2.5X).
(a)Savings of 14 days
compared toes se - .
(b) Savings of 20 days compared to
last drilled Offset (MGR-5).
(a) 14 days
(b) 20 days
PERFORMANCE Total Net Savings 24 Section
~US$ 2.000.000
Considering Operational Costs of US$100.000/day
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Field Results Bit Runs & ROP per wellIV.
24-26 Comparison
BEST PERFORMANCE
rse
ction
[m/h]
Runspe
ROP
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Field Results Drilling curves of 17IV.
Considered as the Best Performance
DHM-RSS
VTK
through Carboniferous formation.
Greater distance drilled per bit
(4.6X
).
TTK-VTK
- - -
ImprovedROP
(2.7X
).
(a) Savings of 24 days compared to
best Offset (MGR-4).
(b)Savings of 33 days
compared to
last drilled Offset (MGR-5).
o a e av ngs ec on
~ US$ 3.300.000
PERFORMANCE(a) 24 days
(b) 33 days
Considering Operational Costs of US$100.000/day
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Field Results Bit Runs & ROP per wellIV.
17 Comparison
ction
ROP[m/h]
Runspers
6 Kymera bits
4 Kymera bits
for 1321m
6 Kymera bits
for 1509.5m
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Field Results RecordsIV.
Ability to drill greater distances at higher ROP
Size Type DD ROP Well Formation
24 HP633X 457 5.3 MGR-6 TARIJA
24 HP633X 429 4.1 MGR-6 TARIJA
17 KM633 382 3.1 MGR-5 TARIJA
17 KM633 328 2.9 MGR-5 ITAC.-TUPAMBI
17 KM633 303 4.2 MGR-5 TAIGUATI-TARIJA
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ConclusionsV.
1. Hybrid Technology (Kymera bits
) greatly adapts to the drilling
2. Drilling Dysfunctions
such as Off Center wear, Rounded Gage, Flat
Cresting and Tracking are greatly minimized or eliminated all together.
3. Synergy between Hybrid bits (Kymera
) and Automated Vertical Drilling
Systems (VertiTrak/TruTrak
) helpsmaximize drilling performances
,
turning difficult environments easy to drill at excellent rates.
4. Get collateral benefits
as improved hole quality, less tortuosity, reduced
borehole instability, less wear of string and casing, less time for runningcasings
5 V b i E i l I t. Very obvious Economical Impact.
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