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 NamePalenque Norte 12FieldDorado Riquelme6 5/813.50N-803 3/42252.76411.856 5/8PRODUCTION HOLE100 Klb (extended)34.00 Klb - for 65 TonEvaluation made byEstrellaStatePunta Arenas714C-904245 1/22.99213.3150 Klb (extended)46.00 Klb - for 75 TonDateCountryChile7 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