Research Article An Integrated Approach for Drilling ...downloads.hindawi.com/archive/2015/281276.pdf · An Integrated Approach for Drilling Optimization Using Advanced Drilling Optimizer

Research ArticleAn Integrated Approach for Drilling OptimizationUsing Advanced Drilling Optimizer

David Hankins Saeed Salehi and Fatemeh Karbalaei Saleh

Petroleum Engineering Department University of Louisiana at Lafayette Lafayette LA 70504 USA

Correspondence should be addressed to Saeed Salehi saeadsgmailcom

Received 13 September 2014 Accepted 5 December 2014

Academic Editor Merv Fingas

Copyright copy 2015 David Hankins et alThis is an open access article distributed under the Creative Commons Attribution Licensewhich permits unrestricted use distribution and reproduction in any medium provided the original work is properly cited

The ability to optimize drilling procedures and economics involves simulation to understand the effects operational parametersand equipment design have on the ROP An analysis applying drilling performance modeling to optimize drilling operations hasbeen conducted to address this issue This study shows how optimum operational parameters and equipment can be predicted bysimulating drilling operations of preexisting wells in a Northwest Louisiana field Reference well data was gathered and processed topredict the ldquodrillabilityrdquo of the formations encountered by inverting bit specific ROP models to solve for rock strength The outputdata generated for the reference well was formatted to simulate upcoming wells A comparative analysis was conducted between thepredicted results and the actual results to show the accuracy of the simulation A significant higher accuracy is shown between thesimulated and actual drilling results Once simulations were validated optimum drilling parameters and equipment specificationswere found by varying different combinations of weight on bit (WOB) rotary speed (RPM) hydraulics and bit specifications untilthe highest drilling rate is achieved for each well A qualitative and quantitative analysis of the optimized results was conducted toassess the potential operational and economic benefits on drilling operations

1 Introduction

As companies continue to expand their drilling operationswithin existing oil and gas fields across the world now isthe time to maximize profitability by optimizing drillingoperations to reduce the associated costs In order to optimizeupcoming wells it is important to understand (1) problemsencountered during previously drilled wells in the samefield (2) the effects drilling parameters and equipmentspecifications have on drilling performance (3) methods ofdetermining the formation strength or ldquodrillabilityrdquo encoun-tered in the wellbore and (4) the applications of drillingoptimizer in simulating upcoming wells Knowing wheninadequate equipment and operational parameters are beingimplemented in the drilling procedure as well as avoidingtheir use allows for drilling and economic optimization Thisapproach was applied to a well-developed field located inNorthwest Louisiana where nonproductive time (NPT) andunnecessary costs occurred due to insufficient operationalparameters and equipment specifications implemented in thedrilling process

Often times in heavily produced fields the drilling processhas become a standard routine procedure especially on landIncreasing drilling performance and minimizing costs in anydrilling operation begin with an accurate understanding ofthe lithological characteristics encountered in the wellboremore importantly the formation rock strength or ldquodrillabilityrdquo[1] Having an accurate estimation of these parameters isvital to reducing costs by improving the overall drillingperformance of any well

Typical methods used to predict rock strength involvemechanical testing on physical cored rock samples [2] testingon rock cuttings [3] evaluating sonic logs [4] and ROPmodeling analyses [5] ROP modeling has come a long waysince Maurer [6] first presented his ldquoperfect-cleaningrdquo theoryfor roller-cone bits In 1994 Hareland and Rampersad pre-sented the standard ROP model for polycrystalline-diamondcompact (PDC) bits The key factor of these ROP modelsis based off of the strength of the formations encounteredduring drilling

While these models are applied to predict the ROP basedoff of bit designspecifications operational parameters and

Hindawi Publishing CorporationJournal of Petroleum EngineeringVolume 2015 Article ID 281276 12 pageshttpdxdoiorg1011552015281276

2 Journal of Petroleum Engineering

06

mile

s

27

miles

20

miles

Figure 1 Satellite imagery of the well locations

formation characteristics their inversion could be solvedto find the confined compressive strength or ldquodrillabilityrdquoof the formation [7 8] Optimizer generates an ApparentRock Strength Log (ARSL) of the rock ldquodrillabilityrdquo for everyfoot of the wellbore by utilizing data from an offset well[9] This ARSL can then be used to simulate and optimizeupcoming wells within the same field by showing the effectschanging operational parameters and equipment designs canhave on the overall drilling performance[7 8] As more wellsin the same field are added in the optimizer for referencethe accuracy of the simulations produced will continue toincrease

2 Field Overview

The field of study is located in Northwest Louisiana Forconfidentiality purposes the name of the field wells andformations included within this study have been changedThe main area of interest is the wellbore sections drilled withan 87510158401015840 PDC bit for each of the three proposed wellsWell AWell B and Well C This section was chosen for analysis dueto the similarities between each well and because measureddepth (MD) can be assumed as true vertical depth (TVD)since the inclination of this section is less than 1∘ for eachwell The three wells are located within the same field and areno more than 27 miles apart from one another (Figure 1)Consequently the same formations were encountered duringthe drilling of this section between each well The formationsencountered during drilling were comprised predominantlyof limestone shale and sandstone that range from UpperJurassic to Lower Cretaceous in age

Well A was used as the reference well in this study The87510158401015840 section of Well A was drilled from 2401 to 8999 feetMDTen formationswere encountered during drilling for thissection of the well Once analyzed the results produced fromWell A were used to simulate Well B

Well B was simulated bymatching its formation tops withthose of Well A This 87510158401015840 section is shorter for Well B

stretching from only 2373 to 7949 feet MD Consequentlyonly eight of the formations encountered during Well A willbe drilled in this section ofWell B Once simulated the resultswere compared to the actual drilling data so that accuracyof the simulation is analyzed when only one well is used forreference

Well C was simulated utilizing data obtained from bothWell A and Well B for reference The 87510158401015840 section of Well Cwas drilled from 2367 to 9097 feet MD This section of thewell is similar to Well A with nine of the same formationsencountered during drilling The simulated results were thencompared with the actual drilling results to determine theaccuracy when two wells are used for reference

Once simulated results had been validated each wellwas optimized by utilizing optimizer The 87510158401015840 section ofeach well was divided into different sections based off theformations encountered so simulations could be conductedto find the most efficient drilling parameters and equipmentdesign for each formation Once separated each forma-tion was optimized by running simulations with differentWOBRPM combinations bit specifications and hydraulicsuntil the most efficient and cost effective parameters arereached Upon completion a cost analysis was conductedto show the effectiveness drilling simulation can have onoptimizing drilling operations in this Northwest Louisianafield

3 Factors Affecting the Penetration Rate inPDC Bits

PDC bits get their name from their drill blank cuttingelements that consist of a layer of synthetic polycrystallinediamond that is attached to tungsten carbide in a high-pressurehigh-temperature (HPHT) process [10] Trying toselect a PDC bit when you have multiple manufacturers tochoose from can be a difficult task for the operator [1 11]Knowledge of the design features and operational conditionsis imperative when optimizing wellbore sections that aredrilled with PDC bits

The design features of PDC bits are one of the mainfactors affecting the ROP Each PDC bit used to drill a wellis chosen specifically for the application at hand Thereforeit is important to understand how variations in PDC designfeatures and specifications can affect the drilling rate TheROP can vary significantly with changes in size of the bitnumber of cutters back-rake angle side-rake angle andjunk-slot area (Figure 2)

PDC bit size and junk-slot area have the most significanteffect on drilling performance However the back-rake angleof the cutters and the number of cutters located on the bithave a moderate effect on the ROP The side-rake angle of aPDC bitrsquos cutters has a minor effect of drilling performance

The ability for the PDC bitrsquos design featuresto cut holeefficiently depends on the operational parameters actingupon them Changes in drilling operational parameters canhave a major effect on the drilling rate (Figure 3) Thereforeit is important to understand how each operational parameterused while drilling can affect the drilling rate An assessment

Journal of Petroleum Engineering 3

Number of cuttersBack rakeSide rake

Junk slot areaBit size

65

55

45

35

25

15

5

0 05 1 15 2 25

ROP

(mh

)

Normalised operational effects

Figure 2 Normalised bit design parameter effect on ROP [7 8]

0 05 1 15 2 25


ROP

(mh

)

45

40

35

30

25

20

15

10

5

WOBRPMHHPNozzles size

Flow rateMWPV

Figure 3 Normalised operational effects on ROP [7 8]

has been conducted to present a generalized understandingthe effect weight on bit (WOB) rotary speed (RPM) andhydraulics and mud characteristics have on the drillingperformance

Increasing weight on bit (WOB) and rotary speed (RPM)have a significant effect on drilling performance This is dueto the fact that asWOB increases the teeth are pushed deeperinto the formation and as RPM increases the cutting rotationsare increased However bit hydraulics must be adjusted toensure cuttings do not impede the bit to formation contact

4 Modeling Drilling Performance fromRock Strength

Over the past decades several methods have been developedto estimate ROP [12] These models are able to predict ROPfrom operational parameters and formation characteristicsAdditionally the inversion of these models can be used topredict the rock strength or ldquodrillabilityrdquo [9] Once rockstrength is established other operational parameters can bechanged to estimate the effects it may have on the drillingperformanceThis can have a significant effect on optimizingdrilling operations [13]

In 1994 Hareland and Rampersad presented a newmodelto predict the ROP of PDC bits that take into account theinteraction between the cutter and rock lithology and bitwear New parameters are introduced for the equivalentbit radius dynamic cutter action lithology coefficients andcutter wear (1) Consider

ROP = 1414 lowastWOB lowast ROP lowast cos120572119878 lowast 119889119887lowast tanΘ

lowast119886

RPM119887 lowastWOB119888

(1)

In (1) ROP is rate of penetration WOB is weight on bitS is drillability strength of the rock 119889

119887is bit diameter 120572 is the

cutter side-rake angle Θ is the cutter back-rake angle and ab and c are cutter geometry correction factors Additionallyrock strength can be estimated by solving for the inversion of(1) as in the following equation

119878 =1414 lowastWOB lowast RPM lowast cos120572

ROP lowast 119889119887lowast tanΘ

lowast119886

RPM119887 lowastWOB119888 (2)

5 Optimization Workflow

The workflow was used for the optimization process in thispaper as shown in Figure 4

Here we describe the workflow in detail

6 Data Processing and Study

The initial phase involves gathering necessary data frompreexisting well(s) that were drilled within the particular fieldof interest Necessary data includes operational parametersbit design and specifications aswell as lithologic informationencountered during drilling This preexisting data is ofsignificant importance since it is used to predict the results ofdifferent drilling scenarios when planning new wells [1] It isimportant that the well(s) used as a reference is a close matchto the upcoming well so there are no major discrepanciesbetween the planned and actual drilling results Data isorganized and input into the necessary file type in order forthe optimizer to generate a simulation for upcoming wellsThese files include ⟨BIT⟩ ⟨LITH⟩ and ⟨DRILL⟩

Necessary data needed to be input into the bit file wasfound from the daily drilling reports and design specifica-tions provided by the bit manufacturer Generation of the bitfile includes information such as bit size depth inout bitwear inout and numbersize of nozzles In addition since


Data processing and study

Filtration and parameters selection

ARSL (Apparent Rock Strength Log)

generation

Simulation validation and postsimulation

analysis

Figure 4

PDC bits are being used in the simulation cutter specifica-tions including numbersize of cutters back-rakeside-rakeangle number of blades and junk slot area were also needed[14] The optimizer predicts drilling performance and bitwear for each bit based on their design specifications [11]Therefore it is imperative that all data input into the ⟨BIT⟩file was accurate prior to running the simulation to ensurethe validity of the results

Input data needed for the ⟨DRILL⟩ file can be found inthe drilling reports of the reference well(s) Drilling recorderslocated on the rig have taken note of all operational param-eters for every foot of the drilling process Necessary dataincludes MDTVD ROP WOB RPM flow rate and mudcharacteristicstype An extensive quality control procedurewas done on the drill file data to remove any erroneousdata entry that is not within the acceptable range Eachacceptable range is defined by standards set by the rigequipment or personnel to ensure equipment is being usedto their designed parameters and that safe drilling practicesare being followed at all times When data points did not fallwithin the acceptable range they were removed and the datawas averaged between the last closest acceptable data points[14]

The final file needed to run the optimizer is the ⟨LITH⟩file In order to generate the lithology file the top depthsand lithologic descriptions were input for every formationencountered when drilling the reference well The necessarydata can usually be found from geology reports or generatedbased on log properties [14] Mud logs are a good datasource since they record lithologic percentages of the cuttingsalong with relevant mud properties for every foot of thedrilling operation Data input into the lithology file includesMDTVD percentages of lithology formation pore pressureand permeability

7 Generating the ARSL

Once the ⟨BIT⟩ ⟨DRILL⟩ and ⟨LITH⟩ files had beencompleted and validated they were used to create an ARSLfor every foot of the reference well Additionally rig costmudmeasure while drilling (MWD) cost and connec-tiontrip times were entered into the optimizer prior togenerating the ARSL so a cost analysis can also be includedThe ARSL is the main component of the drilling simulationand is used as the standard measurement of the unconfinedcompressive strength or the ldquodrillabilityrdquo of the formation [1]

This ARSL is generated by inverting the bit specific ROPdrilling models to solve for the rock strength on a foot byfoot basis [5] Therefore it is recommended that valuesobtained from the ARSL are verified with other rock strength

estimation mechanisms to ensure there is no significantdeviation between one another This can be done by utilizingstrength tests obtained frommechanical laboratory testing onrock cores utilizing data interpretation from other logs orcuttings obtained when drilling

Unlike rock laboratory mechanical testing the ARSLallows the user to know the rock strength at every foot ofthe wellbore determined while drilling Therefore the ARSLis the only form of testing that is capable of generatingthe in situ strength properties of the formations The ARSLthat is obtained could be used to simulate not only theldquodrillabilityrdquo of the formations but several other aspects ofthe petroleum engineering analysis The predicted formationstrengths could be used to estimate the minimum horizontalstress (Sh) along the wellbore [15] These Sh estimations canbe used to help with wellbore stability completion designmethods and produced sand control in reservoirs [1]

8 Developing the Simulation

The ARSL generated from the reference well is used tosimulate the upcoming or future well Since the simulationmust be conducted on wells within the same field formationtops of the reference well are shrunk or expanded to fitthe tops for the well that is being simulated [16] Once theformation tops had been matched to fit the new well theoptimizer correlates the rock strength from the referencewell for the upcoming well This allows the optimizer topredict drilling time bit wear and operational parametersfor the new well [11] However the simulation does not stophere

The ultimate goal of developing a drilling simulation isto optimize the entire process so the lowest cost per footis achieved [17] Therefore several simulations need to beconducted for every section of the wellbore to ensure theoptimum parameters are achieved This includes differentscenarios of WOBRPM adjusting drilling parameters forchanges in ARSL bit type and hydraulics drilling fluid typeand rheology and drilling modes

The best method to increase the ROP of the entire drillingoperation is to separate different sections of the wellboreSections are divided based off changes in lithology or rockstrength A sensitivity analysis should be conducted to seethe effect of changing operational parameters equipmentspecifications or type has on the drilling rate The ultimategoal of conducting a sensitivity analysis is to see the effectschanging parameters has on theROP for that section butmostimportantly the overall drilling performance for the entirewell


7318

9329

11340

13351

15363

17374

19385

21396

23407

25418

27429

00 4000 00 1500 00 250 20 110 10 k 30k 100 250 08 14 00 80

MD

(m)

LITH ARS (MPA) ROP (mhr) WOB (ton) RPM (rpm) FR (Lmin) PV (cp) PP (SG) Wear

SandCoalDolomiteConglomerate

SandstoneShaleLimestone

Figure 5 ARSL generated for reference Well A

9 Results

The results of this work are presented in two parts Firstwe present the results achieved from simulating Well B andWell C using offset reference well data Well B was simulatedusing one well for reference while Well C was simulatedusing two wells for reference Second we present the resultsof optimizing all three proposed wells by finding the bestcombinations of WOB RPM and hydraulics Furthermorean analysis was conducted to see the potential benefits thatcould be obtained by the operator from utilizing drillingperformance modeling applied in the optimizer to simulateupcoming wells within the same field

10 Simulation Validation

The objective of validating the simulations was first to deter-mine the accuracy of simulating wells by utilizing offset welldata within the proposed Northwest Louisiana field Well Bwas simulated utilizing the drilling files generated fromWellA First the ARSL of Well A was generated after necessarydata files were created (Figure 5)Then the formation tops ofWell Awere formatted to fit the tops forWell BThe operatingparameters applied during drilling operations of Well B wereentered into the optimizer to produce the simulation Thesimulated results were then compared with the actual resultsof Well B (Figure 6)

Figure 6 presents a good visual match with the simula-tions produced in the optimizer The average ROP for theentire well was estimated to be 8596 fth when the actualwas approximately 10089 fth giving approximately an 84match While a 16 difference is not as accurate as was

expected there are some sources of error that should be notedWhile the formations encountered are the same there issome variation between the lithologic percentages as shownin Figure 6 The last formation simulated using Well A hasmuch less sand concentrations thanWell BThis ismost likelyattributed due to a slight change in the depositional processesIn addition when only one well is used for reference thesimulation produced takes into account a wider range forthe ARS and ROP This is clearly visible when comparing theARSL of the simulated and actual in Figure 6

The simulation of Well C was produced by utilizing bothWell A and Well B as reference wells Formation tops of theARSL were formatted to fit those for Well C The simulationforWell C was generated by inputting the operational param-eters used whenWell C was drilledThe comparison betweenthe simulated and actual results is presented in Figure 7

Figure 7 presents a much closer match than shownpreviously for the simulation of Well B The average ROPfor Well C was simulated to be 6716 fth while the actualwas approximately 6742 fth giving a match of approximately99 This study cannot guarantee that all simulated resultswill be as accurate as Well C However by comparing thesimulations of Well B and Well C it can be assumed thatas more wells are added for reference the accuracy of thesimulations will continue to increase This is due to thereduction in discrepancies seen between wells

11 Optimization

Once the wells were simulated for this Northwest Louisianafield each section was optimized to find the best operating


7233

8932

10632

12332

14031

15731

17430

19130

20829

22529

24229

MD

(m)

00 4000 00 1500

LITH ARS (MPA) ROP (mhr)



(a)

7233

8932

10632

12332

14031

15731

17430

19130

20829

22529

24229M

D (m

)

00 4000 00 1500




(b)

Figure 6 Comparison of the simulation (a) to the actual (b) for Well B

7215

9266

11317

13369

15420

17471

19522

21574

23625

25676

27728

MD

(m)

00 4000 00 1500




(a)

7215

9266

11317

13369

15420

17471

19522

21574

23625

25676

27728

00 4000 00 1500




MD

(m)

(b)

Figure 7 Comparison of the simulation (a) to the actual (b) for Well C


Table 1 Optimized parameters for Well A

Well A sensitivity analysis resultsFormation Top (ft) Bottom (ft) ROP (fth) WOB (k-lbs) RPM FR (galmin) PV (cp) MW (ppg)1 2401 2628 32464 12 75 555 12 852 2628 2785 26978 10 75 591 12 853 2785 3123 30036 13 85 594 12 864 3123 3970 17602 16 80 597 13 885 3970 5515 9488 20 70 592 14 936 5515 5890 12592 26 90 600 17 967 5890 6426 8320 26 82 580 17 968 6426 8698 5869 30 55 540 16 1009 8698 8925 4911 34 55 540 17 10410 8925 8999 5311 30 55 540 18 104

Table 2 Well A optimization savings potential

ROP (fth) Time (hours) Cost per foot Total costsReal 5545 11100 $16870 $103409734Optimized 8438 7820 $12966 $79477882Savings 2893 3280 $3904 $23931852

parameters for each well The focal point of the optimizationprocess was to reduce drilling time and associated costs overthe entire length of the 87510158401015840 section while ensuring the bitdoes not exceed an IADC wear of 25

The optimum operational parameters of Well A werefound after conducting a sensitivity analysis (Table 1) For-mations 1ndash4 should be drilled with aWOB ranging from 10 to16 k-lbs with a rotary speed ranging from 75 to 85 rpmWOBwill slowly increase between 20 and 26 k-lbs while continuinga high rotary speed ranging from 70 to 90 rpm for formations5-6 Once arriving into the harder more abrasive rock seenin formations 8ndash10WOB should increase from 26 to 34 k-lbswhile reducing the rotary speed to around 55 rpm Utilizingthese operational parameters for the formations shown inTable 1 will control the bit wear so the ROP is increased forthe well

The optimized bit hydraulicsWOBRPM and combinedoptimization values were used to plot the time spent drillingversus the depth drilled (Figure 8) When the bit data usedto drill Well A was changed to the specifications used forWell B and Well C the total drilling time was reduced byapproximately 25 hoursOptimizing the hydraulics of the newbit reduced the total drilling time over another hour givinga total drilling time of approximately 94 hours compared tothe actual of 121 hours Finding the best combination ofWOBand RPM parameters reduced the total drilling time over 43hours from the original drilling time When all parameterswere combined the total drilling time was reduced by over 45hours

The economic impact of the optimized drilling param-eters of Well A is presented in Table 2 Utilizing drillingperformance modeling based off the drilling strength tofind the most efficient parameters has the capability to save

the operator approximately $23931852 for the 87510158401015840 verticalwellbore section of Well A

The optimum operational parameters for Well B werefound after conducting a sensitivity analysis (Table 3) Similarresults are seen between Well A and Well B however sinceWell B was a shorter wellbore section higher WOB and RPMvalues can be implemented since bit wear does not have tobe controlled as much Formations 1ndash4 can be drilled usinga WOB ranging from 14 to 16 k-lbs combined with a rotaryspeed from 75 to 85 rpm WOB can be increased to 20ndash26 k-lbs while rotary speed can be increased from 70 to 90 rpm forformations 5ndash7 However to ensure excessive bit wear doesnot occur before the end of the section is reached rotary speedshould be reduced to 55 rpm for formation 8

The effects of the optimized hydraulics WOBRPMand combined optimization values for Well B were plottedto compare the time spent drilling versus depth drilled(Figure 9) When bit hydraulics were optimized the totaldrilling time was reduced by approximately 8 hours Findingthe best combination of WOB and RPM parameters did nothave a significant effect on the drilling time Optimizingthe WOBRPM parameters for Well B increased the drillingtimes for formations 1ndash7 However by doing this bit wearwas reduced so that the drilling time is reduced over thehard abrasive lithology of formation 8 When all parameterswere combined the total drilling time was reduced by over 10hours

The economic impact of the optimized drilling parame-ters ofWell B is presented in Table 4The operator could havepotentially saved approximately $7359138 for the 875 inchvertical wellbore section of Well B This could be achievedfrom utilizing drilling performance models and offset welldata


140120100806040200

500

1000

1500

2000

2500

3000

Drilling time (hours)140120100806040200

Drilling time (hours)

140120100806040200


140120100806040200


140120100806040200


Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

Real data

Optimized hydraulics Optimized WOBRPM

Complete optimization

Real data

Real data

Real data

New bitReal data

Figure 8 Drilling time versus drilled depth comparison with initial and optimized parameters for Well A

The optimum operational parameters for Well C werefound after conducting a sensitivity analysis (Table 5) Theresults of Well C are much similar to those of Well A sincetheir designs are such a close match Formation 1ndash4 shouldbe drilled with WOB ranging from 10 to 16 k-lbs combined

with a rotary speed of 75ndash85 rpmWOBwill increase from 20to 26 k-lbs while rotary speed will vary from 70 to 90 rpm forformations 5ndash7 When the harder abrasive lithology seen informations 8-9 is reached WOB should be increased to 30ndash34 k-lbs while rotary speed should be reduced to 55 rpm


Table 3 Optimized parameters for Well B

Well B sensitivity analysis resultsFormation Top (ft) Bottom (ft) ROP (fth) WOB (k-lbs) RPM FR (galmin) PV (cp) MW (ppg)1 2373 2678 16657 14 75 555 8 852 2678 2820 19308 14 75 581 9 863 2820 3160 29590 16 85 594 9 864 3160 4022 26207 16 80 597 8 875 4022 5555 14032 20 70 592 9 916 5555 5910 21227 26 90 594 9 927 5910 6460 16125 26 82 555 9 948 6460 7949 6781 30 55 542 11 97

Table 4 Well B optimization savings potential


500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

Real dataOptimized hydraulics

Optimized WOBRPM Complete optimization

Real data

Real dataReal data

6050403020100


6050403020100


6050403020100


6050403020100


Figure 9 Drilling time versus drilled depth comparison with initial and optimized parameters for Well B


Table 5 Optimized parameters for Well C

Well C sensitivity analysis resultsFormation Top (ft) Bottom (ft) ROP (fth) WOB (k-lbs) RPM FR (galmin) PV (cp) MW (ppg)1 2367 2778 24570 12 75 555 8 852 2778 2982 12106 10 75 592 8 863 2982 3320 22274 13 85 594 9 864 3320 4173 14672 16 80 594 9 895 4173 5730 9521 20 70 592 9 936 5730 6083 20925 26 90 599 10 957 6083 6633 18409 26 82 581 11 978 6633 8853 4970 30 55 594 13 989 8853 9097 3064 34 55 594 12 103

Table 6 Well C optimization savings potential

ROP (mh) Time (hours) Cost per foot Total costsReal 6742 10374 $15481 $104186035Optimized 7979 8434 $12521 $84267815Savings 1237 1939 $2960 $19918220

120100806040200



120100806040200



500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)



Real data

Real dataReal data

Figure 10 Drilling time versus drilled depth comparison with initial and optimized parameters for Well C


The effects of the optimized hydraulics WOBRPMand combined optimization values for Well C were plottedto compare the time spent drilling versus depth drilled(Figure 10) When bit hydraulics were optimized the totaldrilling time was reduced by approximately 5 hours Findingthe best combination of WOB and RPM parameters reducedthe drilling time from 107 hours to 87 hoursWhen all param-eters were combined the total drilling time was reduced byapproximately 20 hours

The economic impact of the optimized drilling param-eters of Well C is presented in Table 6 Utilizing drillingperformance modeling and offset well data to simulate wellsuntil the most efficient parameters could potential save theoperator approximately $19918220 for the 87510158401015840 verticalwellbore section of Well C

12 Conclusions

This paper presented a systematic approach to simulate andoptimize the operational plan for upcoming wells using offsetwell data for a field in Northwest Louisiana The followingconclusions can be drawn

(i) Comparison of the simulated and actual results ofthe proposed wells shows simulating upcoming wellsusing formation strength estimates from offset welldata applied with optimizer is accurate for this North-west Louisiana field

(ii) Drilling performance simulations produced for WellB and Well C were 84 and 99 accurate with theactual results

(iii) Comparing the differences in the accuracy of thesimulations forWell B andWell C proves that as morewells are included for reference data discrepanciesbetween the predicted and actual drilling perfor-mance are reduced

(iv) Applying drilling performance modeling based onformation strength is effective in ensuring optimumequipment and operational parameters are imple-mented prior to the drilling of a well in this NorthwestLouisiana field

(v) The results of the optimized bit hydraulics andWOBRPM for Well A Well B and Well C couldpotentially reduce the time spent drilling by 32801010 and 1939 hours respectively

(vi) Had optimum operational parameters been imple-mented the operator could have potentially saved$23931852 $7359138 and $19918220 for Well AWell B and Well C

Conflict of Interests

The authors declare that there is no conflict of interestsregarding the publication of this paper

Acknowledgment

Authors would like to thank Pason Systems Corp for sup-porting and giving access to use optimizer for educationalpurposes

References

[1] G Hareland H R Motahhari J P Hayes and A QureshildquoIncreased drilling-efficiency of gas-storage wells proven usingdrilling simulatorrdquo in Proceedings of the CIPCSPE Gas Technol-ogy Symposium Paper SPE 114798 Calgary Canada June 2008

[2] T Berre L Tunbridge andKHoeg ldquoThemeasurement of smallstrains and K0-values in triaxial tests on clay-shalesrdquo in Pro-ceedings of the 8th International Congress on RockMechanics pp1195ndash1199 Tokyo Japan 1995

[3] F Zausa L Civolani M Brignoli and F J Santarelli ldquoReal-timewellbore stability analysis at the rig-siterdquo in Proceedings of theSPEIADC Drilling Conference Paper SPE 37670 AmsterdamThe Netherlands March 1997

[4] K Tokle P Horsrud and R K Bratli ldquoPredicting uniaxial com-pressive strength from log parametersrdquo in Proceedings of the 61stAnnual Technical Conference and Exhibition of the Society ofPetroleum Engineers Paper SPE 15645 New Orleans Lo USAOctober 1986

[5] P R Rampersad G Hareland and P Boonyapaluk ldquoDrillingoptimization using drilling data and available technologyrdquo inProceedings of the 3rd Latin AmericanCaribbean PetroleumEngineering Conference Paper SPE 27034 Buenos AiresArgentina April 1994

[6] W CMaurer ldquoThe perfect-cleaning theory of rotating drillingrdquoin Proceedings of the 37th Annual Fall Meeting of SPE Paper SPE408 Los Angeles Calif USA October 1962

[7] G Hareland R Nygaard B K Virginillo and H B MunroldquoDrilling simulation improves field communication andreduces drilling cost in Western Canadardquo in Proceedings of thePetroleum Societyrsquos 8th Canadian International PetroleumConference Paper PETSOC 2007-086 Calgary AlbertaCanada June 2007

[8] G Hareland W Yan R Nygaard and J L Wise ldquoCuttingefficiency of a single PDC cutter on hard rockrdquo in Proceedings ofthe Petroleum Societyrsquos 8th Canadian International PetroleumConference Paper 2007-082 Calgary Alberta Canada June2007

[9] R Andrews G Hareland R Nygaard T Engler H Munro andB Virginillo ldquoMethods of logs to quantify drillabilityrdquo inProceedings of the SPE Rocky Mountain Oil and Gas TechnologySymposium Paper SPE 106571 Denver Colo USA April 2007

[10] A T Bourgoyne K K Millheim M E Chenevert and F SYoung Applied Drilling Engineering vol 2 of SPE TextbookSeries 1986

[11] R Nygaard and G Hareland ldquoApplication of rock strength indrilling evaluationrdquo in Proceedings of the SPE 10th Latin Ameri-can andCaribbean PetroleumEngineeringConference (LACPECrsquo07) pp 86ndash92 Buenos Aires Argentina April 2007

[12] R K Bratli G Hareland F Stene G W Dunsaed and G Gjel-stad ldquoDrilling optimization software verified in the North Seardquoin Proceedings of the SPE LACPECConference Paper SPE 39007Rio de Janeiro Brazil September 1997

[13] E C Onyia ldquoRelationships between formation strengthdrilling strength and electric log propertiesrdquo in Proceedings of


the 63rd Annual Technical Conference and Exhibition of theSociety of Petroleum Engineers Paper SPE 18166 Houston TexUSA October 1988

[14] M Fazaelizadeh B Rashidi andGHareland ldquoDrilling-derivedrock strength can simulate upcoming well performancerdquo inProceedings of the Canadian Unconventional Resources andInternational Petroleum Conference SPE-135857-MS Society ofPetroleum Engineers Calgary Canada October 2010

[15] L Song and G Hareland ldquoMinimum horizontal stress profilefrom rock strength formontney formation inNorth East BritishColumbia Canadardquo in Proceedings of the 47th US Rock Mechan-icsGeomechanics Symposium Paper ARMA 13-141 San Fran-cisco Calif USA June 2013

[16] M Rastegar G Hareland R Nygaard and A Bashari ldquoOpti-mization of multiple bit runs based on ROP models and costequation a newmethodology applied for one of the Persian gulfcarbonate fieldsrdquo in Proceedings of the IADCSPE Asia PacificDrilling Technology Conference and Exhibition Paper IADCSPE 114665 Jakarta Indonesia August 2008

[17] GGjelstadGHarelandKNNikolaisen andRK Bratli ldquoThemethod of reducing drilling costs more than 50 percentrdquo inProceedings of the SPEISRM Eurock Paper SPEISRM 47342Trondheim Norway July 1998

International Journal of

AerospaceEngineeringHindawi Publishing Corporationhttpwwwhindawicom Volume 2014

RoboticsJournal of

Hindawi Publishing Corporationhttpwwwhindawicom Volume 2014


Active and Passive Electronic Components

Control Scienceand Engineering

Journal of



RotatingMachinery


Hindawi Publishing Corporation httpwwwhindawicom

Journal ofEngineeringVolume 2014

Submit your manuscripts athttpwwwhindawicom

VLSI Design



Shock and Vibration


Civil EngineeringAdvances in

Acoustics and VibrationAdvances in



Electrical and Computer Engineering

Journal of

Advances inOptoElectronics


Volume 2014

The Scientific World JournalHindawi Publishing Corporation httpwwwhindawicom Volume 2014

SensorsJournal of


Modelling amp Simulation in EngineeringHindawi Publishing Corporation httpwwwhindawicom Volume 2014


Chemical EngineeringInternational Journal of Antennas and

Propagation




Navigation and Observation



DistributedSensor Networks



06

mile

s

27

miles

20

miles

Figure 1 Satellite imagery of the well locations

formation characteristics their inversion could be solvedto find the confined compressive strength or ldquodrillabilityrdquoof the formation [7 8] Optimizer generates an ApparentRock Strength Log (ARSL) of the rock ldquodrillabilityrdquo for everyfoot of the wellbore by utilizing data from an offset well[9] This ARSL can then be used to simulate and optimizeupcoming wells within the same field by showing the effectschanging operational parameters and equipment designs canhave on the overall drilling performance[7 8] As more wellsin the same field are added in the optimizer for referencethe accuracy of the simulations produced will continue toincrease

2 Field Overview

The field of study is located in Northwest Louisiana Forconfidentiality purposes the name of the field wells andformations included within this study have been changedThe main area of interest is the wellbore sections drilled withan 87510158401015840 PDC bit for each of the three proposed wellsWell AWell B and Well C This section was chosen for analysis dueto the similarities between each well and because measureddepth (MD) can be assumed as true vertical depth (TVD)since the inclination of this section is less than 1∘ for eachwell The three wells are located within the same field and areno more than 27 miles apart from one another (Figure 1)Consequently the same formations were encountered duringthe drilling of this section between each well The formationsencountered during drilling were comprised predominantlyof limestone shale and sandstone that range from UpperJurassic to Lower Cretaceous in age

Well A was used as the reference well in this study The87510158401015840 section of Well A was drilled from 2401 to 8999 feetMDTen formationswere encountered during drilling for thissection of the well Once analyzed the results produced fromWell A were used to simulate Well B

Well B was simulated bymatching its formation tops withthose of Well A This 87510158401015840 section is shorter for Well B

stretching from only 2373 to 7949 feet MD Consequentlyonly eight of the formations encountered during Well A willbe drilled in this section ofWell B Once simulated the resultswere compared to the actual drilling data so that accuracyof the simulation is analyzed when only one well is used forreference

Well C was simulated utilizing data obtained from bothWell A and Well B for reference The 87510158401015840 section of Well Cwas drilled from 2367 to 9097 feet MD This section of thewell is similar to Well A with nine of the same formationsencountered during drilling The simulated results were thencompared with the actual drilling results to determine theaccuracy when two wells are used for reference

Once simulated results had been validated each wellwas optimized by utilizing optimizer The 87510158401015840 section ofeach well was divided into different sections based off theformations encountered so simulations could be conductedto find the most efficient drilling parameters and equipmentdesign for each formation Once separated each forma-tion was optimized by running simulations with differentWOBRPM combinations bit specifications and hydraulicsuntil the most efficient and cost effective parameters arereached Upon completion a cost analysis was conductedto show the effectiveness drilling simulation can have onoptimizing drilling operations in this Northwest Louisianafield

3 Factors Affecting the Penetration Rate inPDC Bits

PDC bits get their name from their drill blank cuttingelements that consist of a layer of synthetic polycrystallinediamond that is attached to tungsten carbide in a high-pressurehigh-temperature (HPHT) process [10] Trying toselect a PDC bit when you have multiple manufacturers tochoose from can be a difficult task for the operator [1 11]Knowledge of the design features and operational conditionsis imperative when optimizing wellbore sections that aredrilled with PDC bits

The design features of PDC bits are one of the mainfactors affecting the ROP Each PDC bit used to drill a wellis chosen specifically for the application at hand Thereforeit is important to understand how variations in PDC designfeatures and specifications can affect the drilling rate TheROP can vary significantly with changes in size of the bitnumber of cutters back-rake angle side-rake angle andjunk-slot area (Figure 2)

PDC bit size and junk-slot area have the most significanteffect on drilling performance However the back-rake angleof the cutters and the number of cutters located on the bithave a moderate effect on the ROP The side-rake angle of aPDC bitrsquos cutters has a minor effect of drilling performance

The ability for the PDC bitrsquos design featuresto cut holeefficiently depends on the operational parameters actingupon them Changes in drilling operational parameters canhave a major effect on the drilling rate (Figure 3) Thereforeit is important to understand how each operational parameterused while drilling can affect the drilling rate An assessment




65

55

45

35

25

15

5

0 05 1 15 2 25

ROP

(mh

)



0 05 1 15 2 25


ROP

(mh

)

45

40

35

30

25

20

15

10

5


Flow rateMWPV








lowast119886


(1)






lowast119886












generation


analysis

Figure 4














7318

9329

11340

13351

15363

17374

19385

21396

23407

25418

27429

00 4000 00 1500 00 250 20 110 10 k 30k 100 250 08 14 00 80

MD

(m)





9 Results








11 Optimization



7233

8932

10632

12332

14031

15731

17430

19130

20829

22529

24229

MD

(m)

00 4000 00 1500




(a)

7233

8932

10632

12332

14031

15731

17430

19130

20829

22529

24229M

D (m

)

00 4000 00 1500




(b)


7215

9266

11317

13369

15420

17471

19522

21574

23625

25676

27728

MD

(m)

00 4000 00 1500




(a)

7215

9266

11317

13369

15420

17471

19522

21574

23625

25676

27728

00 4000 00 1500




MD

(m)

(b)
















140120100806040200

500

1000

1500

2000

2500

3000



140120100806040200


140120100806040200


140120100806040200


Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

Real data



Real data

Real data

Real data

New bitReal data









500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)



Real data

Real dataReal data

6050403020100


6050403020100


6050403020100


6050403020100








120100806040200



120100806040200



500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)



Real data

Real dataReal data





12 Conclusions










Acknowledgment


References






















RoboticsJournal of





Journal of



RotatingMachinery





VLSI Design



Shock and Vibration







Journal of



Volume 2014


SensorsJournal of





Propagation












65

55

45

35

25

15

5

0 05 1 15 2 25

ROP

(mh

)



0 05 1 15 2 25


ROP

(mh

)

45

40

35

30

25

20

15

10

5


Flow rateMWPV








lowast119886


(1)






lowast119886












generation


analysis

Figure 4














7318

9329

11340

13351

15363

17374

19385

21396

23407

25418

27429

00 4000 00 1500 00 250 20 110 10 k 30k 100 250 08 14 00 80

MD

(m)





9 Results








11 Optimization



7233

8932

10632

12332

14031

15731

17430

19130

20829

22529

24229

MD

(m)

00 4000 00 1500




(a)

7233

8932

10632

12332

14031

15731

17430

19130

20829

22529

24229M

D (m

)

00 4000 00 1500




(b)


7215

9266

11317

13369

15420

17471

19522

21574

23625

25676

27728

MD

(m)

00 4000 00 1500




(a)

7215

9266

11317

13369

15420

17471

19522

21574

23625

25676

27728

00 4000 00 1500




MD

(m)

(b)
















140120100806040200

500

1000

1500

2000

2500

3000



140120100806040200


140120100806040200


140120100806040200


Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

Real data



Real data

Real data

Real data

New bitReal data









500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)



Real data

Real dataReal data

6050403020100


6050403020100


6050403020100


6050403020100








120100806040200



120100806040200



500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)



Real data

Real dataReal data





12 Conclusions










Acknowledgment


References






















RoboticsJournal of





Journal of



RotatingMachinery





VLSI Design



Shock and Vibration







Journal of



Volume 2014


SensorsJournal of





Propagation













generation


analysis

Figure 4














7318

9329

11340

13351

15363

17374

19385

21396

23407

25418

27429

00 4000 00 1500 00 250 20 110 10 k 30k 100 250 08 14 00 80

MD

(m)





9 Results








11 Optimization



7233

8932

10632

12332

14031

15731

17430

19130

20829

22529

24229

MD

(m)

00 4000 00 1500




(a)

7233

8932

10632

12332

14031

15731

17430

19130

20829

22529

24229M

D (m

)

00 4000 00 1500




(b)


7215

9266

11317

13369

15420

17471

19522

21574

23625

25676

27728

MD

(m)

00 4000 00 1500




(a)

7215

9266

11317

13369

15420

17471

19522

21574

23625

25676

27728

00 4000 00 1500




MD

(m)

(b)
















140120100806040200

500

1000

1500

2000

2500

3000



140120100806040200


140120100806040200


140120100806040200


Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

Real data



Real data

Real data

Real data

New bitReal data









500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)



Real data

Real dataReal data

6050403020100


6050403020100


6050403020100


6050403020100








120100806040200



120100806040200



500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)



Real data

Real dataReal data





12 Conclusions










Acknowledgment


References






















RoboticsJournal of





Journal of



RotatingMachinery





VLSI Design



Shock and Vibration







Journal of



Volume 2014


SensorsJournal of





Propagation










7318

9329

11340

13351

15363

17374

19385

21396

23407

25418

27429

00 4000 00 1500 00 250 20 110 10 k 30k 100 250 08 14 00 80

MD

(m)





9 Results








11 Optimization



7233

8932

10632

12332

14031

15731

17430

19130

20829

22529

24229

MD

(m)

00 4000 00 1500




(a)

7233

8932

10632

12332

14031

15731

17430

19130

20829

22529

24229M

D (m

)

00 4000 00 1500




(b)


7215

9266

11317

13369

15420

17471

19522

21574

23625

25676

27728

MD

(m)

00 4000 00 1500




(a)

7215

9266

11317

13369

15420

17471

19522

21574

23625

25676

27728

00 4000 00 1500




MD

(m)

(b)
















140120100806040200

500

1000

1500

2000

2500

3000



140120100806040200


140120100806040200


140120100806040200


Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

Real data



Real data

Real data

Real data

New bitReal data









500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)



Real data

Real dataReal data

6050403020100


6050403020100


6050403020100


6050403020100








120100806040200



120100806040200



500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)



Real data

Real dataReal data





12 Conclusions










Acknowledgment


References






















RoboticsJournal of





Journal of



RotatingMachinery





VLSI Design



Shock and Vibration







Journal of



Volume 2014


SensorsJournal of





Propagation










7233

8932

10632

12332

14031

15731

17430

19130

20829

22529

24229

MD

(m)

00 4000 00 1500




(a)

7233

8932

10632

12332

14031

15731

17430

19130

20829

22529

24229M

D (m

)

00 4000 00 1500




(b)


7215

9266

11317

13369

15420

17471

19522

21574

23625

25676

27728

MD

(m)

00 4000 00 1500




(a)

7215

9266

11317

13369

15420

17471

19522

21574

23625

25676

27728

00 4000 00 1500




MD

(m)

(b)
















140120100806040200

500

1000

1500

2000

2500

3000



140120100806040200


140120100806040200


140120100806040200


Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

Real data



Real data

Real data

Real data

New bitReal data









500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)



Real data

Real dataReal data

6050403020100


6050403020100


6050403020100


6050403020100








120100806040200



120100806040200



500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)



Real data

Real dataReal data





12 Conclusions










Acknowledgment


References






















RoboticsJournal of





Journal of



RotatingMachinery





VLSI Design



Shock and Vibration







Journal of



Volume 2014


SensorsJournal of





Propagation























140120100806040200

500

1000

1500

2000

2500

3000



140120100806040200


140120100806040200


140120100806040200


Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

Real data



Real data

Real data

Real data

New bitReal data









500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)



Real data

Real dataReal data

6050403020100


6050403020100


6050403020100


6050403020100








120100806040200



120100806040200



500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)



Real data

Real dataReal data





12 Conclusions










Acknowledgment


References






















RoboticsJournal of





Journal of



RotatingMachinery





VLSI Design



Shock and Vibration







Journal of



Volume 2014


SensorsJournal of





Propagation










140120100806040200

500

1000

1500

2000

2500

3000



140120100806040200


140120100806040200


140120100806040200


Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

Real data



Real data

Real data

Real data

New bitReal data









500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)



Real data

Real dataReal data

6050403020100


6050403020100


6050403020100


6050403020100








120100806040200



120100806040200



500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)



Real data

Real dataReal data





12 Conclusions










Acknowledgment


References






















RoboticsJournal of





Journal of



RotatingMachinery





VLSI Design



Shock and Vibration







Journal of



Volume 2014


SensorsJournal of





Propagation














500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)



Real data

Real dataReal data

6050403020100


6050403020100


6050403020100


6050403020100








120100806040200



120100806040200



500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)



Real data

Real dataReal data





12 Conclusions










Acknowledgment


References






















RoboticsJournal of





Journal of



RotatingMachinery





VLSI Design



Shock and Vibration







Journal of



Volume 2014


SensorsJournal of





Propagation














120100806040200



120100806040200



500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)

500

1000

1500

2000

2500

3000

Dril

led

dept

h (m

)



Real data

Real dataReal data





12 Conclusions










Acknowledgment


References






















RoboticsJournal of





Journal of



RotatingMachinery





VLSI Design



Shock and Vibration







Journal of



Volume 2014


SensorsJournal of





Propagation












12 Conclusions










Acknowledgment


References






















RoboticsJournal of





Journal of



RotatingMachinery





VLSI Design



Shock and Vibration







Journal of



Volume 2014


SensorsJournal of





Propagation

















RoboticsJournal of





Journal of



RotatingMachinery





VLSI Design



Shock and Vibration







Journal of



Volume 2014


SensorsJournal of





Propagation











RoboticsJournal of





Journal of



RotatingMachinery





VLSI Design



Shock and Vibration







Journal of



Volume 2014


SensorsJournal of





Propagation









Documents

Research Article An Integrated Approach for Drilling ...downloads.hindawi.com/archive/2015/281276.pdf · An Integrated Approach for Drilling Optimization Using Advanced Drilling Optimizer