Drill Plan AnalysisSEE HERE FIRSTNominalmandatory
cellsDrillabilitySpeedMudCSGWeightsGradesDCsDCs weightDPs ODDPs
IDDPs weightDPs API gradeHWDPDescriptionDragTraveling BlockDrill
linesGas gradientYoptional cellsvery soft120 ft/minOBM7.7H-402
7/8162 3/81.8154.85E753 1/2CONDUCTOR20 Klb (vertical)6.300 Klb -
for 1 Ton6.10 psi/ftNcalculation cellssoft90 ft/minWBM3
1/29.50J-553182 7/81.9956.65X954SURFACE HOLE30 Klb (low angle)7.40
Klb - for 15 Ton8.12 psi/ftmedium60 ft/min4 1/210.50K-553 1/8193
1/22.1516.85G1054 1/2INTERMEDIATE HOLE 140 Klb (high angle)12.90
Klb - for 25 Ton10.15 psi/ftDrilling-Plan Analysishard511.60M-653
1/42042.4419.5S1355INTERMEDIATE HOLE 250 Klb (horizontal)16.70 Klb
- for 35 Ton12.18 psi/ftvery hard5 1/213L-803 1/2214 1/22.60210.45
1/2INTERMEDIATE HOLE 360 Klb (extended)26.500 Klb - for 5 TonWell
Name6 5/813.50N-803 3/42252.76411.856 5/8PRODUCTION HOLE100 Klb
(extended)34.00 Klb - for 65 TonEvaluation made by714C-904245
1/22.99213.3150 Klb (extended)46.00 Klb - for 75 TonDate7
5/815C-954 1/8266 5/83.24013.757 3/415.10T-954 1/4273.34014Hole and
Casing plan8 5/815.50P-1104 1/2293.47615.5Section 1Section 2Section
3Section 4Section 5Max Values [lb][Short Tons]9 5/817Q-1254
3/4303.50015.7Hole SectionshelpSURFACE HOLEINTERMEDIATE HOLE
1INTERMEDIATE HOLE 2PRODUCTION HOLE10 3/4185323.64016.25Depth
fromhelpft01164.7554396.5410335.15011 3/4205 1/8333.82616.6Depth
tohelpft1164.7554396.5410335.1514173.925938.6112 3/421.405
1/2353.95819.2Hole diameterhelpin2617 1/212 1/48 1/213 3/8235
3/4374.00019.5Casing ODhelpin2013 3/89 5/8713
1/223.206384.27620Weightppf106.568513214246
1/8394.40821.9GradeK-55K-55Q-125Q-1251624.106
1/2404.67022.82Lengthft11654397103364068.4418 5/8266
3/4414.77824.7Total casing weight in
airlb12407329899652713613019005271362026.407424.89225.2casing data
(click + for details)help263.56824 1/226.807 1/843Anticipated Hook
Load (casing)helplb124,073298,996527,136130,190527136OPEN HOLE287
1/2445.90125.6297 3/4465.96527.7GENERAL29.70847Hole
DraghelpKlb515302020328 1/848Weight of travelling
assy.helpklb404040400PRODUCTION HOLE32.308 1/250Margin of overpull
for CSGhelpKlb204050405000025.00032.60951Margin of overpull for
drill stringhelpKlb206090909000045.00032.759 1/252Loads
MANDATORY(click + for details)33.709 3/453Expected
torqueftxlb1,2001,6003,0003,500351054Anticipated Hook Load (drill
string)helplb50,000152,000215,000318,00031800025684635.301156Capacity
of the Drill Pipehelp000003612573859Tripping Capabilities3960Min.
tripping speedhelpft/min60606060604061Drill Lines to the
blockhelp10101010040.5063(click + for details)4264Formation /
BOP42.7065BOP installedhelpYYYY42.8067Bottom hole
pressurehelppsi750075007500750043.1068Depth (TVD) from
RKBhelpft1410014100141001410043.5070Gas gradientpsi/ft.10 psi/ft.10
psi/ft.10 psi/ft.10 psi/ft45.3072Anticipated surface
pressurepsi60906090609060900609045.50 No API73(click + for
details)46.1075Hydraulic Needs46.4076Drilling fluid
typeWBMWBMWBMWBM4778densityppg9.19.311.712.547.1079buoyancy
factor0.860.860.820.810.000.004880Flow
Ratehelpgpm7509006404504982Circulating
Pressurehelppsi5073029334832225184(click + for details)SURFACE
HOLE50.1083Preferred Drill String ( for setback capacity)
OPTIONALhelp51.2085Weight of direcctional BHAKlb53.5088Length of
BHAft53.60890.0005490Bottom DCs ODin0.00054.5091weight in
airppf0.00055.3093section lengthft0.00055.5094Total weight in
airlb00000057.109657.60 No API98Top DCs ODin58.4099weight in
airppf59.40100section lengthft60102Total weight in
airlb00000060.7010361.00105HWDPs ODin62.80 No API107weight in
airppf64.90108section lengthft65110Total weight in airlb0000065.10
No API11165.70112Drill Pipes ODin67.30 No API113Drill pipes
IDin68114Nominal weight in airppf68.80 No API116API grade70.10 No
API117Tensile Yieldlb0000070.30119section lengthft0000070.40 No
API120Total weight in airlb000007112272123Weight of drill string in
airlb00000072.10 No API12400000073.20125Total weight in
mud00000075126Total weight00000075.60127(click + for details)76.60
No API12877.00 No API12979.2013080.40 No API13280.70 No API13381.40
No API13482.50 No API1368413785.00 No API13885.3013986.00 No
API14287.5014388.20 No API1449414794.50 No API14994.80 No
API15096.50 No API15299.00 No API15499.30 No API155105.00 No
API157106.50158109160110.00 No API163111.00 No API165114.00 No
API168115.00 No API169118.00 No API171118.50 No API172126.00 No
API174128.00 No API176131.50 No API179133182136.00 No API184139.00
No API185140.00 No API187147.00 No API188162.00 No API192165.00 No
API195169.00 No API198182.00 No API200207.00 No
API203206208209210211212216220221224225227229230232234235237239240243245246248251254257259261281286291295299302307310313315317342347352357361364368371374377379
New Drill Pipe(Class I)Includes weight of Drill string +
directional BHA + Traveling assy + Hole drag + Margin of overpull
for BHATotal Weight in selected mudThe first hole section shall
have a value of 0 (zero) as starting point for drilling. The
subsequent hole sections will start where the previous one finished
- done automaticallyInput the total drilled depth for the hole
section. The data shall be input in feetInput the hole diameter -
bit size if conventional bit, openning size for bicentric or hole
openersThe OD of the casing to be run in that hole sectionOPTIONAL:
Input the details of the casing to be run. The weight in AIR of the
casing will be calculated - Use it as a reference to compare
against the calculated Hook Load for the casingThis is the value
the calculator will use
This value shall:
- Not consider buoyancy.- Not include hole drag.- Not include
margin of overpull.
You decide wheter to include the travelling block or not (you
will be asked in the calculations - next sheet - if it is
included).
For vertical or low angle wells you can use the weight of the
string in air (calculated in the casing data cells). For high angle
or horizontals, a detailed analysis of the hook load has to be
carried out - Recommendation: Use Drillsafe from Drilling Office
and input the data in this cell.
Remember that this value will be less than the weight in air
because the pipe in laying down in the well. Do not misunderstand
this load, after considering the hole drag it will become
considerable higher for horizontals than for vertical wells.
Make sure you input the expected drag and the margin of overpull
for casing in the Loads cells.This is the value the calculator will
use
This value shall:
- Not consider buoyancy.- Not include hole drag.- Not include
margin of overpull.
You decide wheter to include the travelling block or not (you
will be asked in the calculations - next sheet - if it is
included).
For vertical or low angle wells you can use the weight of the
string in air (calculated in the prefered drill string cells). For
high angle or horizontals, a detailed analysis of the hook load has
to be carried out - Recommendation: Use Drillsafe from Drilling
Office and input the data in this cell.
Remember that this value will be less than the weight in air
because the pipe in laying down in the well. Do not misunderstand
this load, after considering the hole drag it will become
considerable higher for horizontals than for vertical wells while
pulling out.
Make sure you input the expected drag and the margin of overpull
for each drill string in the Loads cells.This cell will indicate if
the grade of the selected drill pipe is enough to withstand the
loads, including the margin of overpull. You do not want your
system to fail by breaking the Drill Pipe.
The grade of the Drill Pipe is input in the prefered drill
string cells.
The calculations are done for New Drill Pipe (class I).
The calculator does not consider tapered strings.This is the
value the calculator will use
The tripping speed is used to calculate the power of the
drawwork.
In order to reduce the drawwork power requirements, a reduced
speed for the heaviest strings can be considered. Remember that the
heaviest load is only experienced when the string is on bottom and
the load will be reduce while pulling out - so the speed can be
increased.
The tripping capacity is calculated with the drilling strings
and not with the casing string, which are usually heavier than the
drilling ones. The reason is that the casing strings are not meant
to be pulled out. It is clear though, that the pulling speed of the
casing (in case it is needed) will be lower than the tripping speed
for the drilling string.This is the value the calculator will
use
The number of lines to the block has to be defined; from 6 to 12
lines is the common figure. To choose the number of lines, it is
important to keep in mind that the more lines the more power will
be needed to pull a string at the same speed (since the drawwork
will rotate faster). But the more lines, the less the stresses (and
lower fast line load) and the longer the life of the line.This is
the value the calculator will use
Input Y (yes) or N (no) wheter a BOP will be used for the hole
section or not. This will define the size of the BOP (drill bit
pass through).This is the value the calculator will use
Input the pressure at the top of the hydrocarbon sandsThis is
the value the calculator will use
Input the depth (vertical measured from the rotary table)
related to the pressure above.This value shall be the result of a
detailed hydraulic design, considering hole cleaning, HIS and JIF
among others.This value shall be the result of a detailed hydraulic
design, considering hole cleaning, HSI and JIF among others.The
Drilling Plan analysis spreadsheets is a resume of the well design.
Fill all the required information in the yellow cells (mandatory),
the green cells ara optional and the gray cells perform automatic
calculations.
The spreadsheet is divided into hole sections - a total of five
sections can be included, a detailed analysis of each hole section
is to be done.
Some of the cells have scroll-list menus to choose.
You will find sub menus were data is to be input (click the +
simbols in the leftmost columns). The sub menu called Loads is
mandatory, make sure it is filled out before checking the
calculations in the next spreadsheet (Basic rig calculations).
In order to get help, place your mouse in the "help" symbol, you
will get a description of the information to be input.
After completing the Drilling Plan Analysis, go the next
spreadsheet Basic Rig Calculation to see the resutls.Do not write
on or modify these cells - the calculator will not work if these
cells are modified.The calculator will not work if these cells are
not properly filled out - please read the help comments before
filling the cells.This is a values the calculator will use
Hole Drag: Is a force and is a function of the dynamic
frictional effect. The drag is measured as the different between
the fre static hanging weight and the pick up weight IN MUD, ie.
with buoyancy included.
In the field, the drag can be measured as follows: run the
string just above bottom (do not apply weight on bit), start
rotating the string and write down the weight indicated in the
"martin decker" after a steady state is obtained. This will give
you the free static load (the rotation will eliminate static
frictions). Stop rotation and start picking up the string at a
fixed speed (not too fast), write down the weight after a steady
state is obtained. The difference between these two values is the
hole drag.
Make sure you perform a detailed offset analysis prior to input
the expected hole drag. This value is mandatory to perform an
optimum sizing of the equipment.This is a values the calculator
will use
Weight of travelling assy: The weight of travelling assemblies
have to consider all the weights (not considering drill or casing
strings) that are hanging from the derrick
The weight is dependent on the hook load, so this value is
commonly input after calculating the hook loads. Find below a list
with the weight of common travelling assemblies as a guide (as per
IADC drilling manual). These weights includes elevators, hook,
block and links.
100 ton - 6.3 Klb150 ton - 7.4 Klb250 ton - 12.9 Klb350 ton -
16.7 Klb500 ton - 26.5 Klb650 ton - 34.0 Klb750 ton - 46 KlbThis is
a values the calculator will use
Margin of overpull for CSG and Drill String: Offset analysis
will determine the likelyhood of having stuck pipe problems. Do not
be too conservative: If you do no expect to have stuck pipe
problems, then do not pick a too big margin of overpull, remember
that there are plenty of safety factors already considered. You
might end up overdesigning your equipment.This is a values the
calculator will use
Margin of overpull for CSG and Drill String: Offset analysis
will determine the likelyhood of having stuck pipe problems. Do not
be too conservative: If you do no expect to have stuck pipe
problems, then do not pick a too big margin of overpull, remember
that there are plenty of safety factors already considered. You
might end up overdesigning your equipment.OPTIONAL -
RECOMMENDED:
These cells are used to calculate the Setback capacity.
These cells will help in the design of the BHAs.
For vertical wells the weight in AIR can be used to size the
equipment. However, for high angle and horizontal wells it is
recommended to perform a detailed analysis of the load according to
the directional profile.
As a rule of thumb, consider 2 metric tons per inch of bit to
calculate the required 'available weight on bit'.
The input of the grade of the drill pipe will be used to
calculated wheter the drill pipe can or cannot withstand the
loads.
Use the results to compare against the ANTICIPATED HOOK
LOAD.Select a combination of hole sections. A maximum of five hole
sections can be analyzed.
The conductor pipe is often driven so the drilling rig is not
involved, however, in some areas the first casing run is called
conductor (in other areas it would be called surface casing).
Basic Rig Calculationssee here firstRig Selection
CalculationsyesnoHOSTING CAPACITYHook load in air=527,136 LbCasing
stringTraveling block weight=40,000 Lb(750 tons Travelling
Block)Margin of overpull for string=50,000 LbSafety
factor=1.25Travelling block included in Hook load=noSTATIC HOOK
LOAD=771,420 LbSET BACK CAPACITY=0 LbTRIPPING CAPACITYHook load in
mud=276,846 LbPRODUCTION HOLETripping speed for heaviest string=60
ft/minLines to the block=10Travelling block included in Hook
load=notravelling block weight=40,000 LbHOISTING POWER REQUIRED (AT
DRAWWORKS)=707 HP(With 10 lines to the block)DRILL LINE SIZELines
to the block=10Reeving efficiency=0.810Fast line load=70,017
LbHeaviest casing=44,198 LbHeaviest drill stringMinimum Design
factors=2Running casing3Drilling/trippingHighest fast line load
(with DF)=140,034 LbHeaviest casingRECOMMENDED DRILL LINE=1
1/4inUsing 6x19 IWRC EIPSPUMP REQUIREMENTSMost demanding
scenario=INTERMEDIATE HOLE 1Mech. Efficiency:75%Flow rate=900
gpmHidr. Efficiency:95%Pressure=3029 psiElec. Efficiency:90%Pump.
Efficiency:85%Preferred # of pumps:3note: The efficiencies can be
adjustedPUMP OUTPUT (HYDRAULIC POWER per pump)=624 HPuse green
cells.PUMP INPUT (MECHANICAL POWER per pump)=973 HPBOP
REQUIREMENTSMost demanding scenario (pressure)=SURFACE HOLEBiggest
Hole size w/ BOP (in)=26SURFACE HOLEBOP working pressure=10,000
psiBOP Size (in)=30PIT VOLUME ESTIMATIONLongest open hole
section=5939 ftINTERMEDIATE HOLE 2Active system minimum requiered
volumen=3315 bbl
The tripping capacity is calculated with the drilling strings
and not with the casing string, which are usually heavier than the
drilling ones. The reason is that the casing strings are not meant
to be pulled out. It is clear though, that the pulling speed of the
casing (in case it is needed) will be lower than the tripping speed
for the drilling string.
To calculate the required drawwork power based on the tripping
speed, it is needed to calculate the heaviest drilling load:
HDL = HDS + HD +
TB................................................1
HDLHeaviest Drilling Load (lb)HDSHeaviest Drill String in MUD
(lb)HDHole Drag (lb)TBTravelling Block (lb)The reeving efficiency
considers the losses in the sheaves. It is calculated from the
following equation:
h = (Kn - 1) / [n x (k-1) x Kn].3
hReeving efficiencyKFriction factornNumber of linesAs per API RP
9BThis cell will define the design factor to be used:
Casing - 2Drilling/tripping - 3Based on 110% anticipated surface
pressureThe static hook load is the maximum weight in static
conditions (not tripping) that the derrick/mast and the
substructure can withstand. For instance in a stuck pipe situation,
if a derrick is able to pull up to 1,000 Klb before failure, then
its SHL will be 1,000 Klb (not considering safety margins). This
value has nothing to do with the power of the rig, which is
determined by the power of the drawwork.
SHL = (HAS + TB + MO) * 1.25.3
SHLStatic Hook Load (lb)HASHeaviest String in Air
(lb)TBTraveling Block (lb)MOMargin of Overpull (lb)
A safety factor of 1.25 is commonly used.
When selecting a rig, the Static Hook Load is closely related to
the Setback Capacity. The Setback Capacity is basically the weight
of the longest drilling string that will be racked back in the
derrick. Therefore, the drilling rig will be selected for the
calculated Static Hook Load with a simultaneous Setback Capacity
equal to the longest drilling string to be racked back.The power at
the drawwork is then calculated from:
DP = (TS * HDL) / (550 * RE).....2
DPDrawwork Power (HP)TSTripping Speed (ft/sec)HDLHeaviest
Drilling Load in MUD (lb)REReeving EfficiencyThe main parameter to
calculate the drill line size is the fast line load. The fast line
is the end of the drilling line that is reeled up on the drawwork
drum.
After selecting the number of lines and calculating the reeving
efficiency (as mentioned in the tripping capacity calculations),
the fast line load has to be calculated.
FLL = HS / ( N * RE )...4
FLLFast Line Load (lb)HSHeaviest String (lb)NNumber of lines
(lines strung to the traveling block)REReeving efficiencyThe flow
rate and the estimated pressure for each section is the data
required to calculate the power and the quantity of rig pumps.
Apply the following equation to obtain the output hydraulic
horsepower for the pumps:
HPP = (FR x P) / 1714.....5
HPPOutput Hydraulic Horsepower (HP)FRFlow rate (gpm)Ppressure
(psi)
The calculated power is base on a 100% hydraulic efficiency of
the pump. However, drilling contractors will not go to the maximum
capacity of their pumps since it will be translated into
maintenance increasing and costs, so a 80% is commonly used for
pump operating rating.The Basic rig calculations is a spreadsheet
that uses the data input in the Drilling Plan Analysis to perform
ris sizing.
Use the green cells to adjust some of the parameters.
This is intended to be a guide during rig sizing and the
criteria used for the calculations is specific to this
calculator.
After obtaining the results from this spreadsheet, you can use
the Quick Rig spreadsheet to evaluate the impact of changes in your
design in the rig sizing.
After the rig calculations is completed - go to "weighting
components" spreadsheet to determine the impact of each component
of the rig in the project performance.The setback capacity is
commonly known as the load of the heaviest string that will be
racked back in the mast. The hoisting capacity is commony defined
as the static hook load with a simultaneous setback capacity - this
because the heaviest load is normally the casing and the drill
string is racked back when running casing.This calculation is
performed considering 6x19 IWRC EIPS wire rope - different resutls
will be obtained if using another type of rope.
Find information in the IFP Drilling Data Handbook
Quick Rigsee here firstQuick Rigtype of stringnumber of
linescasingHOSTING CAPACITYdrill string6Total Hook Load
(lb)help=810,000 Lb8Margin of overpull for string (lb)help=100,000
Lb1012Safety factorhelp=1.00STATIC HOOK LOAD=910,000 LbTRIPPING
CAPACITYHeaviest drill string in mud (lb)help=318,000 LbTripping
speed for heaviest string (ft/min)help=60 ft/minLines to the
blockhelp=10HOISTING POWER REQUIRED (AT DRAWWORKS)=709 HPDRILL LINE
SIZELines to the blockhelp=10Reeving efficiencyhelp=0.810Heaviest
String (lb)help=560,000 LbFast line load (lb)help=69,136 LbType of
stringhelp=casingHighest fast line load (with DF)help=138,272
LbRECOMMENDED DRILL LINE=1 1/4inUsing 6x19 IWRC EIPSPUMP
REQUIREMENTSMech. Efficiency:75%Flow rate (gpm)help=900 gpmHidr.
Efficiency:95%Pressure (psi)help=3100 psiElec. Efficiency:90%Pump.
Efficiency:85%Preferred # of pumps:3note: The efficiencies can be
adjustedPUMP OUTPUT (HYDRAULIC POWER per pump)=638 HPuse green
cells.PUMP INPUT (MECHANICAL POWER per pump)=995 HP
Input here the heaviest string to be pulled out of the hole,
include hole drag and weight of travelling assembly (include top
drive weight if available).
The tripping capacity is calculated with the drilling strings
and not with the casing string, which are usually heavier than the
drilling ones. The reason is that the casing strings are not meant
to be pulled out. It is clear though, that the pulling speed of the
casing (in case it is needed) will be lower than the tripping speed
for the drilling string.
To calculate the required drawwork power based on the tripping
speed, it is needed to calculate the heaviest drilling load:
HDL = HDS + HD +
TB................................................1
HDLHeaviest Drilling Load (lb)HDSHeaviest Drill String in MUD
(lb)HDHole Drag (lb)TBTravelling Block (lb)The number of lines to
the block has to be defined; from 6 to 12 lines is the common
figure. To choose the number of lines, it is important to keep in
mind that the more lines the more power will be needed to pull a
string at the same speed (since the drawwork will rotate faster).
But the more lines, the less the stresses (and lower fast line
load) and the longer the life of the lines.
With the number of lines, the reeving efficiency is to be
calculated. The reeving efficiency considers the losses in the
sheaves. The reeving efficiency formula and details can be find in
the IFP Drilling Data Handbook, chapter F.The tripping speed has to
be agreed considering, among others, tripping time. A value from 60
to 120 ft/min is commonly used.The power at the drawwork is then
calculated from:
DP = (TS * HDL) / (550 * RE).....2
DPDrawwork Power (HP)TSTripping Speed (ft/sec)HDLHeaviest
Drilling Load in MUD (lb)REReeving EfficiencyThe static hook load
is the maximum weight in static conditions (not tripping) that the
derrick/mast and the substructure can withstand. For instance in a
stuck pipe situation, if a derrick is able to pull up to 1,000 Klb
before failure, then its SHL will be 1,000 Klb (not considering
safety margins). This value has nothing to do with the power of the
rig, which is determined by the power of the drawwork.
SHL = (HAS + TB + MO) * 1.25.3
SHLStatic Hook Load (lb)HASHeaviest String in Air
(lb)TBTraveling Block (lb)MOMargin of Overpull (lb)
A safety factor of 1.25 is commonly used.
When selecting a rig, the Static Hook Load is closely related to
the Setback Capacity. The Setback Capacity is basically the weight
of the longest drilling string that will be racked back in the
derrick. Therefore, the drilling rig will be selected for the
calculated Static Hook Load with a simultaneous Setback Capacity
equal to the longest drilling string to be racked back.Derricks and
masts are designed to a static hook load capacity when using a
specified number of lines and with an established position for the
dead line anchor. Any change in the number of lines strung or shift
of the dead line anchor position may materially alter the static
hook load capacity.Drilling line and wire lines are known as wire
ropes. The wire rope is composed of three parts: the core, the
strand and the wire.
The drilling line has a metal core with several steel wire
strands braided, or cabled, around it. In ropes with lang lay, the
wire and the strands are twisted in the same direction. In ropes
with regular lay, the wires are twisted in one direction and the
strands in the opposite direction; this makes the drilling line
stiffer but somewhat less prone to rotate. Diameters vary widely
depending on the type of rig, but generally do not exceed 1.5
inches.
Wire ropes are described with numerals and abbreviations, for
instance a 6 x 19 wire rope is translated to a 6-strand rope with
19 wires in each strand.
Select the drill lines based on the API specs 9A tables. The
following example shows a table for a Class 6x19 IWRC EIPS
(Independent Wire Rope Core; Extra Improved Plow Steel)
Compare the fast line load against the breaking strength found
in the table - Select the diameter which has a higher breaking
strength than your calculated fast line loadd (including design
factor).
If the fast line load (with design factor) is equal to 160,000
lb, you will select a 1 1/4" diameter as per the following
table.
Wire Diameter Breaking strength (lb)1 -- 113,8001 1/8 --
143,0001 -- 175,8001 3/8 -- 212,0001 -- 250,000
Tables can be find in the IFP Drilling Data Handbook, chapter
F.The number of lines to the block has to be defined; from 6 to 12
lines is the common figure. To choose the number of lines, it is
important to keep in mind that the more lines the more power will
be needed to pull a string at the same speed (since the drawwork
will rotate faster). But the more lines, the less the stresses (and
lower fast line load) and the longer the life of the lines.
With the number of lines, the reeving efficiency is to be
calculated. The reeving efficiency considers the losses in the
sheaves. The reeving efficiency formula and details can be find in
the IFP Drilling Data Handbook, chapter F.The reeving efficiency
considers the losses in the sheaves. It is calculated from the
following equation:
h = (Kn - 1) / [n x (k-1) x Kn].3
hReeving efficiencyKFriction factornNumber of linesThe first
step is to calculate the heaviest load: Select the heaviest casing
string and the heaviest drilling string, then multiplicate the
casing string by a safety factor of 2 and the drilling string by a
safety factor of 3. The highest number will be the heaviest
string.The main parameter to calculate the drill line size is the
fast line load. The fast line is the end of the drilling line that
is reeled up on the drawwork drum.
After selecting the number of lines and calculating the reeving
efficiency (as mentioned in the tripping capacity calculations),
the fast line load has to be calculated.
FLL = HS / ( N * RE )...4
FLLFast Line Load (lb)HSHeaviest String (lb)NNumber of lines
(lines strung to the traveling block)REReeving efficiencyThis cell
will define the design factor to be used:
Casing - 2Drilling/tripping - 3This is the FLL calculated above
multiplied by the design factor (see type of string)The flow rate
and the estimated pressure for each section is the data required to
calculate the power and the quantity of rig pumps. Apply the
following equation to obtain the output hydraulic horsepower for
the pumps:
HPP = (FR x P) / 1714.....5
HPPOutput Hydraulic Horsepower (HP)FRFlow rate (gpm)Ppressure
(psi)
The calculated power is base on a 100% hydraulic efficiency of
the pump. However, drilling contractors will not go to the maximum
capacity of their pumps since it will be translated into
maintenance increasing and costs, so a 80% is commonly used for
pump operating rating.Three types of efficiencies have to be
considered to calculate the input for the pumps - Electrical,
Mechanical and Hydraulic - Use green cells to change these
values.The maximum flowrate to be used for a given hole section. A
detailed hydraulic program and hole cleaning calculations are
recommended before sizing the equipment.Input the expected pressure
for the same hole section considered for the flowrate - Perform
hydraulic calculations to optimize the HSI and JIF before sizing
the equipment.Input the anticipated maximum hook load in air.
To calculate the static load that the derrick/mast and the
substructure will withstand, it is needed to find the heaviest load
in AIR.
It can be either casing or drilling string, in most cases it
will be the casing string, unless small holes are being
drilled.
For this scenario mud buoyancy or floating cannot be considered
since full evacuation can occur.The Quick Rig spreadsheet can be
used to compare different case scenarios without changing the
original Drilling Plan Analysis.
It is highly recommended that the rig sizing is performed using
the Drilling Plan Analysis spreadsheet first.
"weighting components"see here first"Weighting" TableFOUR
ELEMENTSTimeSafetyEnvironmentQualityno impact0000IMPACT
LEVELlow1111medium2222helphigh3333commentsCOMPONENT OF A RIGA.Mast
or Derrick22228B.Substructure22228C.Drawworks22228D.Mud pumps
performance22228E.Rotary performance/TDS22228F.Drill string
specifications22228G.Solids control equipments and tanks22228H.Well
control equipment22228I.Moving
capabilities22228J.QHSE22228TOTAL800
The "weighting" process objective is to identify the key
components of a generic rig according to the needs of a given
project and area to drill in.
Ten components of a rig and four elements of impact have been
identified. Each component has a certain level of impact in each of
these four elements: Time, safety, environment, quality.
Four levels of impact can be selected:
0 - The component does not have an impact on the element.1 - A
low impact.2 - Medium impact.3 - High impact.
The philosophy behind this approach is that no ideal rig will be
available, so a compromise among the ten components has to be
agreed. In other words, if a component is identify as being the key
element for a project, a high punctuation will be assigned to that
component.
Use previous experience in the area, offset well analysis,
bidding strategies and general experience to prioritize the level
of impact of each component.
After completing the "weighting table", fill the rig rating form
spreadsheets for each competing rig (next five spreasheets).Mast or
Derrick:
High Impact:- Stuck pipe and hole stability problems are
expected.- Deep wells and long hole sections.- High angle,
horizontal wells.
Low Impact:- Shallow wells, slim strings.- Non expected hole
stability problems.Substructure:
High Impact:- Stuck pipe and hole stability problems are
expected.- Deep wells and long hole sections.- High angle,
horizontal wells.- Big BOPs or high well heads will be used (height
of rotary table).
Low Impact:- Shallow wells, slim strings.- Non expected hole
stability problems.Drawworks:
High Impact:- Long hole sections.- High tripping speed is
required.- Heavy strings are used.- Wiper trips is a common
practice.
Low Impact:- Shallow wells where no high tripping speed is
required.- Low drag is expected.- Slim holes.Mud pumps
performance:
High Impact:- Long hole sections.- High flow rate and/or
pressure.- Hole cleaning issues.- Big hole diameters.- High angle
and horizontals.
Low Impact:- Shallow wells and small hole diameters.- Low angle
wells.Rotary performance/TDS:
High Impact:- Complicated directional profiles.- High torque is
expected.
Low Impact:- Low angle wells.- Low torque expected.Drill string
specifications:
High Impact:- Sour environment (H2S - CO2).- Stuck pipe problems
are expected.
Low Impact:- Low angle wells.- Non corrosive environment.Solids
control equipment and tanks:
High Impact:- High flow rates.- Big hole diamaters.- Specific
requirements for drilling fluids.- Environmental issues.- Mud
recycling.- Remote locations.
Low Impact:- Non environmental concerns.- Low flow rates.- Non
low gravity solids problems are expected.- Transport for fluids
systematically available.Well control equipment:
High Impact:- HPHT wells.- High anticipated surface pressure.-
Well control expected problems.- Overpressurized areas.
Low Impact:- Depleted areas/normal gradient areas.- low
pressure.Moving capabilities:
High Impact:- Pad drilling.- Batch drilling.- Long distances in
moving.- Short wells (time).
Low Impact:- Long wells.Consider what would be the impact of a
poor QHSE culture of the drilling contractor in the overall
performance of your project.Each component listed below has an
specific impact on the overall project, depending on local
conditions, type of well, logistics and offset analysis.
As a guide, you will find for each component and example where
the component can have a high impact and where its impact can be
reduced. Use it as a reference.
In order to obtain better results and a bigger picture, it is
recommended that a range of people with different areas of
expertise give their input in the evaluation of the impact.
After the evaluation, the components with higher impact level
are defined as the key components for the project and during the
evaluation of the rigs these components will "weight" more than the
other ones.
Make sure the comment cells are filled out in order to clarify
the criteria used to select the impact level.
Rig#1 Ratingsee here firstDP classxYRig #1 Rating
Form1NpremiunRig OwnerENAPData Submitted by:2Rig IdentificationRig
7Date:3Area of rig usedGOY/NNA. Mast or Derrick - Capacity for
handling casing or drill pipeNeeds improvement0%Just complies30%1.
Static hook loadlb640,000OK70%Fit for purpose100%GOY/NB.
Substructure - load-supporting capacityNeeds improvement0%Just
complies30%1. Maximum pipe setback capacitylb300,000OK70%x2.
Maximum rotary-table supporting capacitylb500,000(irrespective of
setback capacity)Fit for purpose100%3. Corner Loading
capacitylb(for derricks only)GOY/NC. Drawwork - Hoisting and
braking capabilitiesNeeds improvement0%Just complies30%1. Output
powerHP750Hook Loadlb600000OK70%2. Input
motorHP3000Velocityft/min60Fit for purpose100%3. Drill Linetype1
1/4"4. Additional features/commentsGOY/ND. Mud pumps
performanceNeeds improvement0%Just complies30%1. Pump
#1HHPFlowgpmOK70%PressurepsiFit for purpose100%2. Pump
#2HHPFlowgpmPressurepsi3. Pump #3HHPFlowgpmPressurepsiGOY/NE.
Rotary performance/TDSNeeds improvement0%Just complies30%1.
MakeOK70%2. ModelFit for purpose100%3. API openingin4.
PowerRPM(min)RPM(max)HP7. TopDriveSystemspecsfromto6. Ratios
(speed)RPMRatio IRPMRatio IIRPMRatio IIIGOY/NF. Drill String
SpecificationsNeeds improvement0%Just complies30%1. Drill
pipeOK70%#1#2Fit for purpose100%Nominal weightppfWeight per
footppfAPI gradeLengthftODinDate of last inspectionInspection
methodClassOther DP considerations2. Drill
Collars#1#2#3QuantityIDinWeightppfGOY/NG. Solids control equipment
and TanksNeeds improvement0%Just complies30%1. Mud
tanksOK70%DescriptionNumSizeCapacity eachCommentsFit for
purpose100%2. Mud mixing equipmenta. PumpsNumberMakeTypeSizeb.
Prime moverNumberSpecsSizeMud agitating equipment3. Solids control
equipmentTypeNumberMakeSpecs.CommentsGOY/NH. Well Control
equipmentNeeds improvement0%Just complies30%a. Blow out
preventersOK70%DescriptionMakeAPI flange sizeWorking
pressureCommentsFit for purpose100%b. AccumulatorDescribec. WC
accessoriesKelly CockDrill pipe safety valvesInside
BOPDegasserMud-Gas separatorOthersGOY/NI. Moving capabilitiesNeeds
improvement0%Just complies30%OK70%Fit for purpose100%GOY/NJ.
QHSENeeds improvement0%Just complies30%OK70%Fit for
purpose100%GOY/NCOSTSDayRate:Stand-by Rate:Mob/deMob rate:Force
Mayeure:Comments:23Rig OwnerENAPData Submitted by:0Rig
IdentificationRig 7Date:31-Dec-99Intended area of rig
used0"weighting" TableRIGA.Mast or
Derrick80B.Substructure85.6C.Drawworks80D.Mud pumps
performance80E.Rotary performance/TDS80F.Drill String
Specifications80G.Solids control equipment and Tanks80H.Well
Control equipment80I.Moving capabilities80J.QHSE80TOTAL80THIS RIG
HAS A NO-GO COMPONENT - IT CANNOT BE SELECTEDRIG RATING0points
Each feature of the rig being assessed will be compared against
the calculated requirements.
Input the information of the rig you are assessing in the green
cells. Then evaluate the rig according to the needs of the well -
to do this you have 5 options:
-No Go: either it works or not, if a N is selected then no
further evaluation of this rig will be done. The rig is
automatically rejected.
- Acceptable: The rig does not fully comply with your
requirements but you can "survive" by making some changes.
- OK: The rig has a minimum compliance for that component. It
might be very restrictive or too high.
- Preferable: The rig component is fulfilling your
expectations.
- Fit fr purpose: This is the ideal component capabilities you
are looking for.
At the bottom of the spreadsheet you will find the rig rating
according to the evaluation and the "weighting" of the components
previously done - in "weighting components" sheet.
Rig#2 Ratingsee here firstDP classxYRig #2 Rating
Form1NpremiunRig OwnerData Submitted by:2Rig
IdentificationDate:3Area of rig usedGOY/NA. Mast or Derrick -
Capacity for handling casing or drill pipeNeeds improvement0%Just
complies30%1. Static hook loadlbOK70%Fit for purpose100%GOY/NB.
Substructure - load-supporting capacityNeeds improvement0%Just
complies30%1. Maximum pipe setback capacitylbOK70%2. Maximum
rotary-table supporting capacitylb(irrespective of setback
capacity)Fit for purpose100%3. Corner Loading capacitylb(for
derricks only)GOY/NC. Drawwork - Hoisting and braking
capabilitiesNeeds improvement0%Just complies30%1. Output
powerHPHook LoadlbOK70%2. Input motorHPVelocityft/minFit for
purpose100%3. Drill Linetype4. Additional features/commentsGOY/ND.
Mud pumps performanceNeeds improvement0%Just complies30%1. Pump
#1HHPFlowgpmOK70%PressurepsiFit for purpose100%2. Pump
#2HHPFlowgpmPressurepsi3. Pump #3HHPFlowgpmPressurepsiGOY/NE.
Rotary performance/TDSNeeds improvement0%Just complies30%1.
MakeOK70%2. ModelFit for purpose100%3. API openingin4.
PowerRPM(min)RPM(max)HP7. TopDriveSystemspecsfromto6. Ratios
(speed)RPMRatio IRPMRatio IIRPMRatio IIIGOY/NF. Drill String
SpecificationsNeeds improvement0%Just complies30%1. Drill
pipeOK70%#1#2Fit for purpose100%Nominal weightppfWeight per
footppfAPI gradeLengthftODinDate of last inspectionInspection
methodClassOther DP considerations2. Drill
Collars#1#2#3QuantityIDinWeightppfGOY/NG. Solids control equipment
and TanksNeeds improvement0%Just complies30%1. Mud
tanksOK70%DescriptionNumSizeCapacity eachCommentsFit for
purpose100%2. Mud mixing equipmenta. PumpsNumberMakeTypeSizeb.
Prime moverNumberSpecsSizeMud agitating equipment3. Solids control
equipmentTypeNumberMakeSpecs.CommentsGOY/NH. Well Control
equipmentNeeds improvement0%Just complies30%a. Blow out
preventersOK70%DescriptionMakeAPI flange sizeWorking
pressureCommentsFit for purpose100%b. AccumulatorDescribec. WC
accessoriesKelly CockDrill pipe safety valvesInside
BOPDegasserMud-Gas separatorOthersGOY/NI. Moving capabilitiesNeeds
improvement0%Just complies30%OK70%Fit for purpose100%GOY/NJ.
QHSENeeds improvement0%Just complies30%OK70%Fit for
purpose100%GOY/NCOSTSDayRate:Stand-by Rate:Mob/deMob rate:Force
Mayeure:Comments:23Rig Owner0Data Submitted by:0Rig
Identification0Date:31-Dec-99Intended area of rig used0"weighting"
TableRIGA.Mast or Derrick80B.Substructure80C.Drawworks80D.Mud pumps
performance80E.Rotary performance/TDS80F.Drill String
Specifications80G.Solids control equipment and Tanks80H.Well
Control equipment80I.Moving capabilities80J.QHSE80TOTAL800RIG
RATING0points
Each feature of the rig being assessed will be compared against
the calculated requirements.
Input the information of the rig you are assessing in the green
cells. Then evaluate the rig according to the needs of the well -
to do this you have 5 options:
-No Go: either it works or not, if a N is selected then no
further evaluation of this rig will be done. The rig is
automatically rejected.
- Acceptable: The rig does not fully comply with your
requirements but you can "survive" by making some changes.
- OK: The rig has a minimum compliance for that component. It
might be very restrictive or too high.
- Preferable: The rig component is fulfilling your
expectations.
- Fit fr purpose: This is the ideal component capabilities you
are looking for.
At the bottom of the spreadsheet you will find the rig rating
according to the evaluation and the "weighting" of the components
previously done - in "weighting components" sheet.
Rig#3 Ratingsee here firstDP classxYRig #3 Rating
Form1NpremiunRig OwnerData Submitted by:2Rig
IdentificationDate:3Area of rig usedGOY/NA. Mast or Derrick -
Capacity for handling casing or drill pipeNeeds improvement0%Just
complies30%1. Static hook loadlbOK70%Fit for purpose100%GOY/NB.
Substructure - load-supporting capacityNeeds improvement0%Just
complies30%1. Maximum pipe setback capacitylbOK70%2. Maximum
rotary-table supporting capacitylb(irrespective of setback
capacity)Fit for purpose100%3. Corner Loading capacitylb(for
derricks only)GOY/NC. Drawwork - Hoisting and braking
capabilitiesNeeds improvement0%Just complies30%1. Output
powerHPHook LoadlbOK70%2. Input motorHPVelocityft/minFit for
purpose100%3. Drill Linetype4. Additional features/commentsGOY/ND.
Mud pumps performanceNeeds improvement0%Just complies30%1. Pump
#1HHPFlowgpmOK70%PressurepsiFit for purpose100%2. Pump
#2HHPFlowgpmPressurepsi3. Pump #3HHPFlowgpmPressurepsiGOY/NE.
Rotary performance/TDSNeeds improvement0%Just complies30%1.
MakeOK70%2. ModelFit for purpose100%3. API openingin4.
PowerRPM(min)RPM(max)HP7. TopDriveSystemspecsfromto6. Ratios
(speed)RPMRatio IRPMRatio IIRPMRatio IIIGOY/NF. Drill String
SpecificationsNeeds improvement0%Just complies30%1. Drill
pipeOK70%#1#2Fit for purpose100%Nominal weightppfWeight per
footppfAPI gradeLengthftODinDate of last inspectionInspection
methodClassOther DP considerations2. Drill
Collars#1#2#3QuantityIDinWeightppfGOY/NG. Solids control equipment
and TanksNeeds improvement0%Just complies30%1. Mud
tanksOK70%DescriptionNumSizeCapacity eachCommentsFit for
purpose100%2. Mud mixing equipmenta. PumpsNumberMakeTypeSizeb.
Prime moverNumberSpecsSizeMud agitating equipment3. Solids control
equipmentTypeNumberMakeSpecs.CommentsGOY/NH. Well Control
equipmentNeeds improvement0%Just complies30%a. Blow out
preventersOK70%DescriptionMakeAPI flange sizeWorking
pressureCommentsFit for purpose100%b. AccumulatorDescribec. WC
accessoriesKelly CockDrill pipe safety valvesInside
BOPDegasserMud-Gas separatorOthersGOY/NI. Moving capabilitiesNeeds
improvement0%Just complies30%OK70%Fit for purpose100%GOY/NJ.
QHSENeeds improvement0%Just complies30%OK70%Fit for
purpose100%GOY/NCOSTSDayRate:Stand-by Rate:Mob/deMob rate:Force
Mayeure:Comments:23Rig Owner0Data Submitted by:0Rig
Identification0Date:31-Dec-99Intended area of rig used0"weighting"
TableRIGA.Mast or Derrick80B.Substructure80C.Drawworks80D.Mud pumps
performance80E.Rotary performance/TDS80F.Drill String
Specifications80G.Solids control equipment and Tanks80H.Well
Control equipment80I.Moving capabilities80J.QHSE80TOTAL800RIG
RATING0points
Each feature of the rig being assessed will be compared against
the calculated requirements.
Input the information of the rig you are assessing in the green
cells. Then evaluate the rig according to the needs of the well -
to do this you have 5 options:
-No Go: either it works or not, if a N is selected then no
further evaluation of this rig will be done. The rig is
automatically rejected.
- Acceptable: The rig does not fully comply with your
requirements but you can "survive" by making some changes.
- OK: The rig has a minimum compliance for that component. It
might be very restrictive or too high.
- Preferable: The rig component is fulfilling your
expectations.
- Fit fr purpose: This is the ideal component capabilities you
are looking for.
At the bottom of the spreadsheet you will find the rig rating
according to the evaluation and the "weighting" of the components
previously done - in "weighting components" sheet.
Rig#4 Ratingsee here firstDP classxYRig #4 Rating
Form1NpremiunRig OwnerData Submitted by:2Rig
IdentificationDate:3Area of rig usedGOY/NA. Mast or Derrick -
Capacity for handling casing or drill pipeNeeds improvement0%Just
complies30%1. Static hook loadlbOK70%Fit for purpose100%GOY/NB.
Substructure - load-supporting capacityNeeds improvement0%Just
complies30%1. Maximum pipe setback capacitylbOK70%2. Maximum
rotary-table supporting capacitylb(irrespective of setback
capacity)Fit for purpose100%3. Corner Loading capacitylb(for
derricks only)GOY/NC. Drawwork - Hoisting and braking
capabilitiesNeeds improvement0%Just complies30%1. Output
powerHPHook LoadlbOK70%2. Input motorHPVelocityft/minFit for
purpose100%3. Drill Linetype4. Additional features/commentsGOY/ND.
Mud pumps performanceNeeds improvement0%Just complies30%1. Pump
#1HHPFlowgpmOK70%PressurepsiFit for purpose100%2. Pump
#2HHPFlowgpmPressurepsi3. Pump #3HHPFlowgpmPressurepsiGOY/NE.
Rotary performance/TDSNeeds improvement0%Just complies30%1.
MakeOK70%2. ModelFit for purpose100%3. API openingin4.
PowerRPM(min)RPM(max)HP7. TopDriveSystemspecsfromto6. Ratios
(speed)RPMRatio IRPMRatio IIRPMRatio IIIGOY/NF. Drill String
SpecificationsNeeds improvement0%Just complies30%1. Drill
pipeOK70%#1#2Fit for purpose100%Nominal weightppfWeight per
footppfAPI gradeLengthftODinDate of last inspectionInspection
methodClassOther DP considerations2. Drill
Collars#1#2#3QuantityIDinWeightppfGOY/NG. Solids control equipment
and TanksNeeds improvement0%Just complies30%1. Mud
tanksOK70%DescriptionNumSizeCapacity eachCommentsFit for
purpose100%2. Mud mixing equipmenta. PumpsNumberMakeTypeSizeb.
Prime moverNumberSpecsSizeMud agitating equipment3. Solids control
equipmentTypeNumberMakeSpecs.CommentsGOY/NH. Well Control
equipmentNeeds improvement0%Just complies30%a. Blow out
preventersOK70%DescriptionMakeAPI flange sizeWorking
pressureCommentsFit for purpose100%b. AccumulatorDescribec. WC
accessoriesKelly CockDrill pipe safety valvesInside
BOPDegasserMud-Gas separatorOthersGOY/NI. Moving capabilitiesNeeds
improvement0%Just complies30%OK70%Fit for purpose100%GOY/NJ.
QHSENeeds improvement0%Just complies30%OK70%Fit for
purpose100%GOY/NCOSTSDayRate:Stand-by Rate:Mob/deMob rate:Force
Mayeure:Comments:23Rig Owner0Data Submitted by:0Rig
Identification0Date:31-Dec-99Intended area of rig used0"weighting"
TableRIGA.Mast or Derrick80B.Substructure80C.Drawworks80D.Mud pumps
performance80E.Rotary performance/TDS80F.Drill String
Specifications80G.Solids control equipment and Tanks80H.Well
Control equipment80I.Moving capabilities80J.QHSE80TOTAL800RIG
RATING0points
Each feature of the rig being assessed will be compared against
the calculated requirements.
Input the information of the rig you are assessing in the green
cells. Then evaluate the rig according to the needs of the well -
to do this you have 5 options:
-No Go: either it works or not, if a N is selected then no
further evaluation of this rig will be done. The rig is
automatically rejected.
- Acceptable: The rig does not fully comply with your
requirements but you can "survive" by making some changes.
- OK: The rig has a minimum compliance for that component. It
might be very restrictive or too high.
- Preferable: The rig component is fulfilling your
expectations.
- Fit fr purpose: This is the ideal component capabilities you
are looking for.
At the bottom of the spreadsheet you will find the rig rating
according to the evaluation and the "weighting" of the components
previously done - in "weighting components" sheet.
Rig#5 Ratingsee here firstDP classxYRig #5 Rating
Form1NpremiunRig OwnerData Submitted by:2Rig
IdentificationDate:3Area of rig usedGOY/NA. Mast or Derrick -
Capacity for handling casing or drill pipeNeeds improvement0%Just
complies30%1. Static hook loadlbOK70%Fit for purpose100%GOY/NB.
Substructure - load-supporting capacityNeeds improvement0%Just
complies30%1. Maximum pipe setback capacitylbOK70%2. Maximum
rotary-table supporting capacitylb(irrespective of setback
capacity)Fit for purpose100%3. Corner Loading capacitylb(for
derricks only)GOY/NC. Drawwork - Hoisting and braking
capabilitiesNeeds improvement0%Just complies30%1. Output
powerHPHook LoadlbOK70%2. Input motorHPVelocityft/minFit for
purpose100%3. Drill Linetype4. Additional features/commentsGOY/ND.
Mud pumps performanceNeeds improvement0%Just complies30%1. Pump
#1HHPFlowgpmOK70%PressurepsiFit for purpose100%2. Pump
#2HHPFlowgpmPressurepsi3. Pump #3HHPFlowgpmPressurepsiGOY/NE.
Rotary performance/TDSNeeds improvement0%Just complies30%1.
MakeOK70%2. ModelFit for purpose100%3. API openingin4.
PowerRPM(min)RPM(max)HP7. TopDriveSystemspecsfromto6. Ratios
(speed)RPMRatio IRPMRatio IIRPMRatio IIIGOY/NF. Drill String
SpecificationsNeeds improvement0%Just complies30%1. Drill
pipeOK70%#1#2Fit for purpose100%Nominal weightppfWeight per
footppfAPI gradeLengthftODinDate of last inspectionInspection
methodClassOther DP considerations2. Drill
Collars#1#2#3QuantityIDinWeightppfGOY/NG. Solids control equipment
and TanksNeeds improvement0%Just complies30%1. Mud
tanksOK70%DescriptionNumSizeCapacity eachCommentsFit for
purpose100%2. Mud mixing equipmenta. PumpsNumberMakeTypeSizeb.
Prime moverNumberSpecsSizeMud agitating equipment3. Solids control
equipmentTypeNumberMakeSpecs.CommentsGOY/NH. Well Control
equipmentNeeds improvement0%Just complies30%a. Blow out
preventersOK70%DescriptionMakeAPI flange sizeWorking
pressureCommentsFit for purpose100%b. AccumulatorDescribec. WC
accessoriesKelly CockDrill pipe safety valvesInside
BOPDegasserMud-Gas separatorOthersGOY/NI. Moving capabilitiesNeeds
improvement0%Just complies30%OK70%Fit for purpose100%GOY/NJ.
QHSENeeds improvement0%Just complies30%OK70%Fit for
purpose100%GOY/NCOSTSDayRate:Stand-by Rate:Mob/deMob rate:Force
Mayeure:Comments:23Rig Owner0Data Submitted by:0Rig
Identification0Date:31-Dec-99Intended area of rig used0"weighting"
TableRIGA.Mast or Derrick80B.Substructure80C.Drawworks80D.Mud pumps
performance80E.Rotary performance/TDS80F.Drill String
Specifications80G.Solids control equipment and Tanks80H.Well
Control equipment80I.Moving capabilities80J.QHSE80TOTAL800RIG
RATING0points
Each feature of the rig being assessed will be compared against
the calculated requirements.
Input the information of the rig you are assessing in the green
cells. Then evaluate the rig according to the needs of the well -
to do this you have 5 options:
-No Go: either it works or not, if a N is selected then no
further evaluation of this rig will be done. The rig is
automatically rejected.
- Acceptable: The rig does not fully comply with your
requirements but you can "survive" by making some changes.
- OK: The rig has a minimum compliance for that component. It
might be very restrictive or too high.
- Preferable: The rig component is fulfilling your
expectations.
- Fit fr purpose: This is the ideal component capabilities you
are looking for.
At the bottom of the spreadsheet you will find the rig rating
according to the evaluation and the "weighting" of the components
previously done - in "weighting components" sheet.
Rig comparisonsee here firstRIG COMPARISONName of the rigRig
ownerRig ratingNormalized rig rating (%)Planned time per well
(days)Expected NPT (%)Normalized time per wellTotal number of
wellsDayrateRig
7ENAP0NO0.00.00000.0%0.00.0%0.000.00000.0%0.00.0%0.000.00000.0%0.00.0%0.000.00000.0%0.00.0%0.000.0Name
of the rigRig ownerTotal cost for moving the rig to projectCost of
modifications (if any) or repairs during the executionCost of
moving from well to wellMiscelaneous costs per wellNormalized cost
per wellNormalized cost for entire projectNormalized dayrate (based
on planned days per well)Rig
7ENAP0.00.00.00.00.0000.00.00.00.00.0000.00.00.00.00.0000.00.00.00.00.0000.00.00.00.00.0
This sheet is a resume of the evaluation of the rigs.
The Normalized dayrate considers all the costs related to the
rig, including the potential increase in cost due to a reduced
efficiency.
The normalized dayrate is the final criteria for rig selection -
The lower normalized dayrate represents the best available option
for the project in terms of overall cost after considering the
impact of the equipment in time, safety, environment and
quality.
TablesTraveling Block Assembly WeightsCapacity (Metric
Tons)Weight (lb) [Hook + Block + Elevator +
Links)100630015074002501290035016700500265006503400075046000