01 planning
TRANSCRIPT
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Proper planning is key to
optimizing operations and
minimizing expenditures
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The drilling engineer's job is todevelop oil and gas reserves at
minimum cost
Oil companies are in the business to
make money
If we do not make money, we cannot
stay in business
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The drilling plan can be anythingfrom a single sheet of paper toseveral books
It depends upon the complexityof the well
Data acquisition
The first step in formulating anydrilling plan is to gather informationfor drilling the well
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Some information is always available
Geologic prognosis
The geologic prognosis contains
information about the formation to bedrilled
It should define the objectives of the well
It should indicate the types of logsrequired and whether cores and drill
stem tests will be required
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Example in bookName and Location:
Dry Hole No. 1-"A", 700' FNL & 660'
FEL Section 82, Block B-1, H&GNSurvey, Northwest Mendota Field,Roberts County, Texas.
Objective Horizon and Contract
Depth: Base of Upper Morrow Sandplus 100' (30m); Approved depth11,350' (3460m)
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Estimated Formation TopsEstimated Elevation, KB 2,857' 871m
Top Wichita-Albany Anhydrite 2,950' 899m
Top Wolfcamp Dolomite 4,150' 1,265m
Top Possible Lost Circulation 4,300' 1,311m
Top Douglas Sands 7,100' 2,164m
Top Granite Wash 9,950' 3,033m
Top 13 Finger Lime 10,910' 3,325m
Top Morrow Formation 11,100' 3,383m
Top Morrow Sand 11,165' 3,408m
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Possible Producing Zones:Douglas Sand 7,100-7,200' 2,164-2,194m
Stray Douglas Sand 7,400' 2,256m
Des Moines 9,050-9,900' 2,758-2,018m
Granite Wash 9,950-10,800' 3,033-3,292m
Upper Morrow Sand 11,165' 3,403m
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Samples:Catch 10' (3m) samples from 6,800' (2070m) to
TD. Wash thoroughly, air dry, and tie in 100'(30m) bundles. 10' (3m) drilling time from 3,350'(1020m) to TD.
Coring:One 50' (15m) oriented core of Upper Morrow
Sand 11,165 to 11,215, (3,403m to 3,418m)approximately. (Need core for dipmeter study and
environmental analysis.)
Drill Stem Testing:Possibly one test in Granite Wash
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Surveys:Dual Induction and Compensated Neutron
Formation Density logs
Remarks:Set surface casing at 3,350' (1021m); set
intermediate casing at 10,950' (3,338m) (5
1/2 139.7mm). Possible string of 2 1/2"
(64mm) tubing to be set outside of 5 1/2"
(139.7mm) casing in order to test Granite
Wash.
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Geologic mapProvides
information on
offset wells thatcan be used for a
reference
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Geologic mapsGeologic cross
section and
structure
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Control wellsControl wells should be geologically
similar to the well being planned
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Bit recordInformation from offset bit records
can show
Casing points
Mud weights
Deviation
Time to drill
Number of bits
Types of bits
Hydraulics
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Open hole logsInformation on formation types
Caliper log can indicate hole stability
Pore pressures from shale values
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Drilling mud recap and proposalRecommended mud program
Information on offset wells
Time required to drill offsets
Hole problems
Mud properties
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Scout ticketInformation on
productive
horizons andproduction rates
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Once all the information iscollected, it is the drilling
engineers responsibility to
develop a drilling plan
Improvements in drilling
practices are always possible
and expected in an area
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Local problems and drillingconditions must be analyzed
with respect to a broad, ever
changing expertise in order todevelop the best possible drilling
program
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Be a skepticIt is our responsibility as drilling
engineers to question drilling
practices which are inconsistent withsound judgment or other experiences
in similar areas
Can the well be drilled moreefficiently and at a lower cost
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Develop expertise in every phaseof drilling
Learn all you can
Spend time on the rig to become
familiar with operations
Don't close your mind to new
technology or the experience of
others
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Establish realistic objectivesStick to facts, data, and statistics
Don't do anything simply
because it's the established
routine
Time is the most important factorAll efforts should be directed at
reducing time
P ANNING
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Attack general practices in viewof new technology
For real savings, attack the
hazards
Attack the abnormal pressure
problems, the deviation, the lost
circulation, or the pipe sticking
problems
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Support conclusions andrecommendations with data,
analysis, and calculations
Follow up and honestly evaluate
your efforts
Report success and failures alike
Don't place blame; find solutions
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The Technical Limit (Drillingthe Limits) is defined as the
best possible well construction
performance for a given set ofdesign parameters
The technical limit is a well design
process by which drilling andcompletion costs are reduced
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The assumption is made thatcosts are time driven
Up to 70% of drilling costs are time
dependent
If the amount of time on location
can be reduced, the cost of the
well can be reduced
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This reduction requiresextraordinary effort and
commitment challenging the
common mindset and philosophyof the drilling personnel
PLANNING
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The technical limit approach consists of
answering three questions.What is the current performance? Or what is
the historical or actual performance of wells
near the location?What is a possible and achievable
performance? Alternately, what is the
theoretical limit of the performance in this
location?What resources or investments are needed to
achieve the theoretical or technical limit?
PLANNING
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Offset wells are evaluated in detailfor time required to drill and
complete
Based on the gathered
information, the well drilling plan
is broken down into many tasks
Complicated wells may have more
than 100 separate tasks
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The time is broken up intoTheoretical well time,
Conventional lost or down time, and
Invisible lost time
Theoretical
Well Time
Conventional
Lost or Down
Time
Invisible Lost
Time
Industry Normal Well Time
Actual Well Duration
Technical Limit
PLANNING
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Technical limit requires muchmore in-depth well analysis and
planning
Each phase of the drilling operationmust be broken down into it's parts
On complicated wells, planning may
take as much as six month andthousands of man hours
PLANNING
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ExampleTime to drill 12 hole (311mm)
Pick up BHA
Trip in hole
Test casing
Drill out shoe track
Drill formation
Leak off test
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ExampleTime to drill 12 hole (311mm)
Drilling
Surveying
Tripping
Circulating
Formation evaluation
Etc.
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After the time breakdown, everydetail must be analyzed by a
team
The team includes drilling,completion, production, reservoir,
service companies, drilling contractor,
permitting, purchasing andmanagement
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Field personnel need to be includedas part of the planning andimplementation
During the actual wellconstruction, the time for eachoperation must be tracked
Deviation from the technical limitmust be explained and solutionsoffered
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A post well analysis isconducted after the well
construction is completed
Summarize the lessons learned
Give possible solutions to eliminate
the lost time
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There cannot be an environmentwhere the parties are looking for
someone to blame
It must be:
What are the problems
What are the solutions
How can we improve
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Jones and Poupet reported 20%
improvement from the best previousoffset well performance and 25%cost reduction from the budgetedamount
41
31
27.25
21.63
15
0 5 10 15 20 25 30 35 40 45
Days
Historical Estimate
Historical Estimate with
One Improved Task
Best Well in the field
Well Drilled after the
Alternate Planning
Technical Limit
PLANNING
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The technical limit approachprovides an immediate benefit ofreduced costs to construct a well
It intensifies planning andengineering effort
Challenges the established practicesand procedures
Creates an opportunity for betterperformance and thereby, accelerateswell construction activities
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The technical limit approachshould not be designed to
surpass the regulatory, health
and safety issues related to welldevelopment
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The approach improves wellconstruction time, and hencewould need careful resource
planning during the constructionphase as well as after theconstruction activity is over
It does no good to drill faster if youhave to wait on equipment orpersonnel because they are not thereon time
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As with any new activity, therewill be a learning curve for
implementing and reaping full
benefits from the new approach
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Extending The Alternate Approachto Drilling Cost Management
Time dependent costs e.g. drilling rig
rate etc.
Time independent variable costs e.g.
mud, cement etc.
Fixed costs e.g. casing, well heads,mobilization, demobilization etc.
PLANNING
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Extending The Alternate Approachto Drilling Cost Management
A much larger improvement can be
achieved by also including time-independent costs into the planning
procedure
The time-independent cost elementcan be 30-60% of the well cost
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Extending The Alternate Approachto Drilling Cost Management
The planning should begin even before
the bids are floated for the welldevelopment