Drilling Bits Design and Types - Presentation
- 2. Concept CUTTING TOOL PLACED ON THE BOTTOM OF THE DRILL STRING TO CUT ROCKS BY APPLIENG WEIGHT AND ROATATION. BIT CLASSIFICATIION IS: l TRICORNE BITS. l FIXED CUTTERS BITS. l SPECIAL BITS.
- 3. OBJECTIVES • PARTS IDENTIFICATION. • DESIGN FEATURES. • NOMENCLATURE. • CUTTING MECHANICS • FORMATIONS. • APPLIED HYDRAULICS
- 4. OBJECTIVES • DRILLABILITY INDEX. • PERFORMANCE EVALUATION. • WEAR & TEAR. •OPERATONAL PROCEDURES. • BICENTRIC.
- 6. Parts Identification TRICON BITS ¡ A.- PIN ¡ B.- LEG ¡ C.- CONE ¡ D.- GAUGE ¡ E.- COMPENSATOR ¡ F.- BEARING ¡ G.- NOZZLE ¡ H.- SEAL E A B G H C F F D
- 7. Parts Identification FIXED CUTTERS BITS ¡ A.-PIN. ¡ B.- MAKE UP SLOT. ¡ C.-GAUGE ¡ D.- DISPLACEMENT PATH ¡ F.- NOSE ¡ G.- TAPER ¡ H.- CONE G A B C D E F H
- 8. DESIGN FEATURES ¡ CUTTING STRUCTURE. ¡ BEARING SYSTEM. ¡ SEALS. ¡ CONES.
- 27. Bearing System
- 28. BEARING SYSTEM
- 29. BEARING SYSTEM
- 47. CONE RETENTION COMPARISONS • Ball Bearing Retention – Concentrated Point Loads – Cyclic Point Loading Causes Spalling • Threaded Ring Retention – Surface Contact – No Spalling – Reduces Lost Cone Rate by Two-Thirds – Optional Cutter Materials
- 48. Bearing Life is Difficult to Predict Primary Reason : Variable Downhole Conditions Customers Expect Confident Prediction of Bearing Life Bearing Failure Depends on Events
- 50. BEARING LIFE ESTIMATION PROCESS Gather Baseline Data Lithology Bit Records Dull Bits / Photos Operation Reports Drill Function Recordings Daily Directional Mud Personal Observations Bearing Life Estimation Process Identify and Cull Outliers Quantify Competitive Performance Measurement Method Numeric Target Demonstrate Expectations
- 51. SEAL MINIMUM TOLERANCES OF SELFLUBRIOCATED BEARING ALLOWES USE OF INCLINED SEAL FACES WHICH ALLOW MAX BEARING LOADING. ALSO USE NONROTATORY SEAL THAT AVOIDS THE JAMMING. SEALED BEARING GARANTEES EFFECTIVE BEARING LUBRICATION AND BETTER BARRIER PERFORMANE.
- 54. SEAL
- 55. CONES ¡ CONE OFFSET DEPENDS ON BIT TYPES, INTERFERENCE DESIGN , FORMATION ¡ ITS VALUE IS DICTATED FORMATION TYPE.
- 58. CUTTING STRUCTURE MADE ON CONES MOUNTED ON BIT LEGSTHAT ARE INTEGRAL PARTS OF THE BIT. RADIAL LOADS ARE TAKEN BY THE MAJOR EXTERNAL ELEMENT WHICH ARE THE BERAINGS. THERE ARE THREE MAIN DESIGS: • BEARINGS STANDARD WITH ROLLERS AND SMALL BULLETS. • SELFLUBRICATION BEARINGS WITH ROLLERS AND SMALL BULLETS. • SELGLUBRICATED FRICITON BEARINGS
- 59. CONES ¡ PINION ANGLE DEPENDS ON CONE DIAMETER, FORMATION , AND TYPE AND DIAMETER OF THE BIT. Angulo de piñon journal en barrena de formación dura Piñon de balero journal
- 69. CUTTING STRUCTURE • CHISEL FORM •HARDFACING
- 74. SINCE THE CONES ARE FORCED TO ROTATE AROUND THE CENTER THEY SLIP AS THEY ROTATE PRODUCING SCRAPIN & ROLLING (DRILLING). CUTTING STRUCTURE
- 85. CUTTING STRUCTURE ¡ FIXED CUTTERS BITS THEY ARE COMPACT BODIES WITHOUT MOVING PARTS; CUTTERS CAN BE: ¡ NATURAL DIAMOND: LIMITED USE IN VERY HARD AND ABRASIVE SPECIAL CASES. ¡ THERMALLY STABLE BITS (TSP): USED TO DRILL HARD ROCKS (LIMESTONE, BASALT, HARD FINE SANDS).
- 86. CUTTING STRUCTURE ¡ POLICRYSTALI DIAMOND COMPACT BITS(PDC): ¡ CUTTERS ( SENTHETIC DIAMOND- COMPACT OF DIAMOND) ATTACHED TO BIT BODY ¡ ITS HIDRAULICO DESIGN IS MADE WITH SYSTEM OF NOZZLERAULIC DESIGN IS MADE SOMILLAR TO THE TRICONE BITS
- 89. CUTTING STRUCTURE SPECIAL BITS.- CAN BE: HOLE OPNNERS OR BICENTRIC, EMPLOYED TI INCRESE AN ALREADY DRILLED SMALLER HOLE DIAMETER.
- 90. CUTTING STRUCTURE ¡ CUTTER DESIGN ¡ HEIGHER ABRASION RESISTANCE. ¡ HEIGHER IMPACT RESISTANCE. ¡ ROCK VOLUME. FIXED CUTTERS (PDC, TSP) RADX AXSYM DIAX
- 91. CUTTING STRUCTURE WEAR 1. Inner cut structure (all inner rows) fixed cutters bits use 2/3 of bit radius. 2. - Outer cut structure (Only gauge row.) In columns 1 and 2 uses linear scale from the 0 to 8 to describe cutter conditions: Steel Teeth middle tooth wearing down thru loss of height. 0 – No lost, wears / broken inserted. fixed Cutters bits wears and/or broken cutters. 0 – No loss, wears and/or broken cutters. 8 – total loss, wear and / or broken cutters.
- 92. IADC ROLLER BIT CLASSIFICATION
- 93. 93 IADC CLASSIFICATION – TRICON BIT 8-1/2” EHP 51 5 17 G Soft Formations with Low Compressive Strength and High Drillability 1 Medium to Medium Hard Formations with High Compressive Strength 2 Hard Semi-Abrasive and Abrasive Formations 3 Soft Formations with Low Compressive Strength and High Drillability 4 Soft to Medium Formations with Low Compressive Strength 5 Medium Hard Formations with High Compressive Strength 6 Hard Semi-Abrasive and Abrasive Formations 7 Extremely Hard and Abrasive Formations 8 INSERT BITS STEEL TOOTH BITS SERIES & CUTTING STRUCTURE CUTTING STRUCTURE TYPE (1 TO 4) 1 ; SOFTEST FORMATION IN A SERIES 4 HARDEST FRORMATION IN SAME SERIES BEARIN DESCRIPTION Standard Roller Bearing 1 Roller Bearing Air Cooled 2 Roller Bearing Gauge Protected 3 Sealed Roller Bearing 4 Sealed Roller Brg - Gauge Protected 5 Sealed Friction Bearing 6 Sealed Frction Brg Gauge Protected 7 AVIALBLE FEATURES (OPTIONAL) A - Air Application B - Special Bearing Seal C - Center Jet D - Deviation Control E - Extended Nozzles G - Gauge/Body Protection H - Horizontal Steering Appl. J - Jet Deflection L - Lug Pads M - Motor Application S - Standard Steel Tooth T - Two Cone Bit W - Enhanced Cutting Structure X - Predominantly Chisel Tooth Insert Y - Conical Tooth Insert Z - Other Shape Insert
- 95. IADC ROLLER BIT CLASSIFICATION
- 105. CUTTING STRUCTURE WEAR INNER AREA 2/3 RADIUS CUTTING AREA 1/3 RADIUS TRICONE ZONNING N- NOSE ROW CONE # M- MIDDLE ROW 1 G- GAUGE ROW 2 A- ALL ROWS 3 FIXED CUTTER BITS C- CONE H- NOSE T- TAPER S- SHOULDER G- GAUGE H- ALL AREAS
- 106. BARING & GAUGE WEAR SEALS, BEARING & STANDARD BEARING: USE A LINEAR SCALE TO ESTIMATE BEARING LIFE. 0- NO WEAR. 8- WEAR, COMPLETELY WORN OUT. SEALED BEARING: E- SEAL EFFECTIVE F- FAILED SEAL. N- CAN NOT BE DETERMINED. X- PDC/TSP BITS GAUGE: MEASURE IN 1/16”: 1- IN GAUGE 1- 1/16” LOSS OF GAUGE 2- 2/16” LOSS OF GAUGE A- 4/16” LOSS OF GAUGE
- 107. REASONES TO POH BIT BHA: BIT CHANGE, END OF DRILLING DMF: DHM FAILURE. DSF : DRILLSTRING FAILURE. DST : DRILL STEM TEST. DP : PLUGGED.CM: MUD CONDITIONS. CP : CORE POINT. FM : FORMATION CHANGE. HP : HOLE PROBLEMS. LOG : LOGGING. PP : PUMP PRESSURE. PR : ROP. RIG : RIG REPAIRE. TD : TOTAL DEPTH. TQ : TORQUE. WC : WEATHER.
- 108. COMMON BIT SIZES
- 109. TOLERANCE FO NEW BITS
- 113. IF WE UNDERSTAND THE APPLICATION WE CAN APPLY THE DESIGN FEATURES NECESSARY TO ADDRESS THAT APPLICATION.
- 118. IADC 1992 WEAR EVALAUTION Exter CUTTING STRUCTURE Inter WEAR CARACT. Des. ZONE BEARING / SEALS GAUGE OTHER WEAR CARACT. REASON POH 1 2 3 4 5 6 7 8 1 INTERNAL CODE STRUCTURE(ALL INTERNAL ROWS) 2 EXTERNAL CUTTING STRUCTURE(GAUGE ROWS ONLY) 3 WEAR FEATYRES (Use CODES OF CODE STRUCTURE) 4 LOCATION (WHERE WEAR FEATURES OCCURE) 5 BEARINGs /SAELS (CONES CONDITIONS) 6 GAUGE (FIANL GAUGE DIAMETER) 7 OTHE WEAR FEATURES ( NOT LIMITED TO CUTTING STRUCTURE) 8 REASON TO POH (WHY FINISH BIT RUN) 8 CODES
- 119. CUTTING STRUCTRE Inter Exter WEAR CHAREC.. Localiz. BEARING / SEALS GAUGE OTHER WEAR CHARAC. REASON POH 1 2 3 4 5 6 7 8 3 WEAR FEATURE (USES ONLY CUTTING STRUCTURE CODE) * SHOW CONE NUMBER AND LOCATION (4) *BC – BROKEN CON BF – BEARING FAILURE BT – BROKEN TOOTH/CUTTER BU - BOLD UP BIT *CC – CRACKED CONE *CD – CEASED CONE CI - CONS INTERFERENCE CR - CROWN CT – CHIPPED TOOTH/CUTTER ER - EROSSION FC – PALIN WEAR HC – HEAT CRACK JD – JUNK DAMAGE *LC – LOST CONE LN – LOST NOZZLE LT – LOST TOOTH/CUTTER Perdidos OC – ECCENTRIC WEAR PB - ----- BIT (Contraída) PN – PLLUGGED NOZZLE NO – NON FEATURE WEAR NR – DO NOT RE-RUN RG – ROUNDED GAUGE RR – RE-RUN RO – “O” ROGo SD – SKIRT DAMAGE SS – SELF SHARPENING WEAR TR - TREAD WO – WASHE OUT WT –WORN TOOTH/CUTTER
- 120. IADC CODE ¡ TRICONE BIT ¡ A-B-C-S ¡ A.- CUTTING STRUCTURE(1-8). ¡ B.- CUTTING STRUCTURE TYPE ( 1-4). ¡ C.- BEARING/GAUGE ( 1-7). ¡ S.- SPECIAL FEATURES (16)
- 121. IADC CODE ¡ FIXED CUTTERS BITS ¡ A-B-C-P ¡ A.-BODY MATERIAL. ¡ B.-CUTTER DENSITY. ¡ C.- CUTTER SIZE/TYPE. ¡ P.-PROFILE.
- 122. TSP BIT TIPO S-248
- 123. HYBRID BIT
- 125. GEOLOGICAL PROCESSES & ROCKS MAGMATICS ROCKS MATURATIONN-EROSSION-TRANSPORT: SEDIMENTES SEDIMENTARY ROCKS METAMORPHISM PROCESS COMPACTION DIAGENESIS PROCESS METAMORPHIC ROCK
- 126. FORMATIONES CLASTIC SEDIMENTARY ROCKS: FORMED OF FRANGMENTS OF CLASTIC ROCKS ( PARTICULES OF MINERALS OR OTHER ROCKS THE PRE-EXISTED THEM. CHEMICAL SEDIMENTARY ROCKS: FORMED BY PREICPITATION, EVAPORATION, CHEMICAL REACTIONS OF SALINE SOLUTIONS. ORGANIC SEDIMETARY ROCKS: FORMED FROM RESTS OF ORGANIC MATERERS ( PLANTS AND ANIMALS). SEDIMENTARY ROCKS CLASTIC CHEIMICAL ORGANIC CONGLOMERATES CALCITES BITUMINE SANDSTONE DOLOMITES CARBON LIMONITES SANDS DISTADITES ESQUISTOS GYPSUM LIMESSTONES SALT/ ANHIDRITE
- 127. FORMATIONES THEY POSSE: •POROSITY: INTERGRANULAR VOID SPACE IN A ROCK. •PERMEABILITY: ROCK FLUID CONDUCTIVITY .
- 128. FORMATIONES HYDROCARBONE ACCUMMULATION POROUS ROCKS THAT STORE FLUIDS SUCH AS SANDSTONE AND LIMESTONE. RESEROVIRS TRAPS WHERE FLUIDS ARE ACCUMMULATED. THEY CAN BE DEVHYDROCARBONE EXTRACTION. THEY ARE CLASSIFIED BY: -T YPE OF ENERGY. -TYPE OF ROCK. -TYPE OF FLUID.
- 129. FORMATIONES a) IGNEOUS ROCKS.-COOLING OF EARTH FUSED MATTER b) Rocas sedimentarias.- DISINTEGRATION OF IGNEOUS ROCKS DUE TO WEATHER FACTORS AND TRANSPORT OF FRAGMENTS CREATED SEDEMENTARY ROCKS SEDIMENTARY ROCKS ARE CLSAAIFIED FURTHER INTO: *CLASTIC ROCKES. *CHEMICAL ROCKS. *ORGANIC ROCKS.
- 131. APPLIED HYUDRAULICS ¡ OPTIMIZATION CRITERIA l MAX IMPACT FORCE. l MULIC HORSEPOWER
- 136. APPLIED HYUDRAULICS ¡ Caída De Presión en Toberas ¡ Índice de Caballaje Hidráulico
- 139. Bit Balling • Cuttings adhere to cutter surface and to hole bottom. • Reduces effective length of teeth. • Occurs in many formations, not just gumbo shales. • Balling reduces penetration rate.
- 148. APPLIED HYUDRAULIC PRESSURE DROP IN TUBES BIT AREA: p 2 2 TFA = 4 (D) = 0.7854 (D) WHERE : 0.7854 =p / 4 D= BIT DIAMETER. JET AREA: p 2 TFA= 4 (D) x N WHERE: D= NOZZLE DIAMETER N: NUMBER OF NOZZELS OF SAME DIAMETER.
- 149. APPLIED HYUDRAULIC PRESSURE DROP AT BIT 2 2 Pbit= MW x Q/ 10858 x A tob WHERE: MW= MUD WEIGH PPG. Q= FLOW RATE GPM. 10858= CONVERSION CONSTANT.
- 150. APPLIED HYUDRAULIC HYDRAULIC POWER INDEX IHHP = Pbit x Q /1714 x BIT AREA WHERE: 1714= CONSTANT.
- 151. APPLIED HYUDRAULIC OPTIMUM HOLE CLEANING IS VERY IMPORTANT DURING DRILLING OPERATIONS. MUD PUMPS PROVIDE FLWORATE AND PRESSURE TO ACHIEVE SUCH TASK. ALSO BIT HYDRAULIC HORSEPOWER NEED BE DESIGNED TO IMPLEMENT THE TASK BHPH= PQ / 1714 WHER HPH= HYDRAULIC HORSPOWER P= PRESSURE PSI Q= FLOWRATE GPM 1714= Constant.
- 152. APPLIED HYUDRAULICS AVIALBLE SURFACE HORSEPOWER: MAX SURFACE PRESSURE X ALLOWABLE FLOWRATE FLOWRATE RANGE REQUIRED TO CLEAN THE HOLE IS: Min.- 30 gal/in OF BIT DIAMETER. Optim.- gal/in OF BIT DIAMETER Max.- gal/in OF BIT DIAMETER.
- 153. APPLIED HYUDRAULICS DESIGN METHODS: 1.- HYDRAULIC IMPACT FORCE. 2.- BIT HYDRAULIC HORSEPOWER. PRESSURE DROP AT DIFFERENT FLOWRATES NEED BE CALCULATED IN BOTH METHODES. THEE DESIGN CRITERIA: 1.- UNLIMITED SURFACE PRSSURE. 2.- LIMITED SURFACE PRSSURE. 3.- ALTERNATE OF INTERMEDIATE SURFACE PRESSURE TO CALCULATER PRSSURE LOSSES IN THE SYTEM: Pc = KQ 1.80
- 154. APPLIED HYUDRAULICS Pc= PRESSURE LOSSSES IN THE SYSTEM WITHOUT BIT PSI. K= CONSTANT (1714). Q= FLOWRATE GPM. WHEN SUFRACE PRESSURE IS LIMITED, POWER PERCENTAGE APPLIED AT THE BIT TO OBTAIN MAX VALUES ARE: *MAX IMPACT FORCE: HPHb= 0.48 HPHs. *MAXHYDRAULKIC HORSEPOWER: HPHb= 0.65 HPHs.
- 155. DRILLABILITY TEST ¡ DETERMINE OPTIMUM OPERATING CONDITIONS. ¡ AS A FUNCTIION OF ROCK STRENGTH. ¡ BASED ON TUBULAR ELONGATIONAND COMPRESSION. ¡ EASY APPLICAION. ¡ PROCEDURE.
- 156. DRILLABILITY TEST *DETERMINE OPTIMUM OPERATING CONDITIONS MAX AND MIN WOB & RPM BASED ON BIT DESIGN. PREDETERMINE VARIOUS OPERATING CONDITIONS E.G.: 5T WOB& 40 RPM, 10T WOB & 60 RPM, 15T WOB & 80 RPM, 30T WOB & 100 RPM, etc. MARK 1M OF KELLY IN 10 OR 20 CM SECTIONS. DRILL VARYING OPERATING CONDITIONS AS GIVEN ABOVE; RECORDING TIME PER SECTION MARKED; THIS GIVE THE DRILLABILITY TIMES. THE TEST CAN BE REPEATED BY USING THE SAME WOB BUT WITH DIFFERENT PREDETERMINED RPMS. CAHNGING WOB & RPM UNTIL OPTIMUM DRILLING CONDITIONS ARE ACHIEVED.
- 157. DRILLABILITY TEST 50 5 TIME 1= 5 min TIME 2= 9 min TIME 3= 10 min TIME 4= 6 min 10 15 20 25 30 35 WOB T 60 70 80 90 100 110 120 130 140 150 RPM
- 158. PERFORMANCE EVALUATION ¡ COST PER METER ¡ MAX ALLOWABLE TIME
- 159. PERFORMANCE EVALUATION COST PER METER CM= CB + (HV + HT)CE / M WHERE: CB= BIT COST($). HV= TRIP TIME(HR). HT= DRILL TIME(HR). CE= RIG COST($/HR). M= METERS DRILLED.
- 160. PERFORMANCE EVALUATION OBJECTIVE; OBTAIN MIN COST PER METR DRILLED WHICH INVOLEVES: 1.- BIT COST. 2.- RIG OPERATING COST. 3.- BIT EFFECTIVE TIME IN HOURS. 4.- TRIP TIME TO CHANGE BIT. 5.- CONNECTION TIME THROUGHOUT BIT LIFE. 6.- DRILLED INTERVAL BY BIT.
- 161. PERFORMANCE EVALUATION COST PER METR VS. DRILLING TIME CURVE IS PLOTTED (AVERAGE COST) OPTIMUM BIT LIFE IS DETERMINED WHEN THE COST PER METER STARTS INCREASING. DRILLER MUST CHECK STRING WEIGHT AT TSHIFT CHANGE AND NOTE IF DRAG OR SLACK OCCURE. ALSO BIT TORQUE, DECREASE IN CIRCULATING RATE AND PRESSURE MUST BE CHECKED ALL THESE MUST BE RECORDED EVERY SHIFT.
- 162. PERFORMANCE EVALUATION “COST PER METER VS DEPTH CURVE” 5 10 15 20 25 30 35 40 45 50 ROTATING TIME(hrs) 0 7000 6000 5000 4000 3000 2000 1000 DEPTH (M)
- 163. PERFORMANCE EVALUATION ROTATING TIME(hrs) 0 5 10 15 20 25 30 35 40 45 50 7000 6000 5000 4000 3000 2000 1000 DEPTH (M)
- 164. CUTTING STRUCTRE Inter Exter WEAR CHAREC.. Localiz. BEARING / SEALS GAUGE OTHER WEAR CHARAC. REASON POH 1 2 3 4 5 6 7 8 3 WEAR FEATURE (USES ONLY CUTTING STRUCTURE CODE) * SHOW CONE NUMBER AND LOCATION (4) *BC – BROKEN CON BF – BEARING FAILURE BT – BROKEN TOOTH/CUTTER BU - BOLD UP BIT *CC – CRACKED CONE *CD – CEASED CONE CI - CONS INTERFERENCE CR - CROWN CT – CHIPPED TOOTH/CUTTER ER - EROSSION FC – PALIN WEAR HC – HEAT CRACK JD – JUNK DAMAGE *LC – LOST CONE LN – LOST NOZZLE LT – LOST TOOTH/CUTTER Perdidos OC – ECCENTRIC WEAR PB - ----- BIT (Contraída) PN – PLLUGGED NOZZLE NO – NON FEATURE WEAR NR – DO NOT RE-RUN RG – ROUNDED GAUGE RR – RE-RUN RO – “O” ROGo SD – SKIRT DAMAGE SS – SELF SHARPENING WEAR TR - TREAD WO – WASHE OUT WT –WORN TOOTH/CUTTER WEAR & TEAR CODE
- 165. TRICONE BIT LOST CONE(LC) POSSIBLE CAUSES SEAL FAILURE EROSION BOUNCING
- 166. TRICONE BIT OFFCENTER (OC) POSSIBLE CAUSES OFF CENTER DRILLING FORMATION CHANGE BAS STABILIZATION INADEQUATE WOB
- 167. TRICONE BIT WORN TEEETH (WT)
- 168. TRICONE BIT LOST INSERTS (LT) POSSIBLE CAUSES: MATERIAL FAILIURE. CONE FRACTURE.
- 171. PDC/TSP CENTER RING (CR) POSSIBLE CAUSES: EXCESSIVE WOB IMPROPER CLEANING FORMATION CHANGE
- 185. BICENTRIC BITS CONCEPT 1.- SLIM HOLE DRILLING WITH UNCONVENTIONAL HOLE DIAMETER & GEOMETRY. 2.- LACK OF ADVANCEMENT IN HYDRAULIC HOLLE OPNERS 3.-SONTINGENCY CASING STRING (16”, 11 7/8”, 11 ¾”) MECHANICAL/GEOLOGICAL EVENTS REQUIRE THE SETTING OF AN UNPLANNED CASING STRING IN ORDER TO REACH PLANNED WELLS OBJECTIVES.
- 186. BICENTRIC BITS REAMING LAXIS DRILLING AXIS
- 187. GEOMETRY a b c d rd e rn rp a a.- WELLBORE AXIS b.- CENTRAL NOMINAL REAMING AXIS. Rd= DRILLING RADIUS. Rn= REAMING RADIUS. Rp=PILOT HOLE RADIUS. a=1/2 REAMER ARCH
- 188. GEOMETRY A B C PILOT DIAMETER STABILIZES BIT DURING DRILLING A.- TRIP DIAMETER DEFINE INTERNAL MIN DIAMETER FOR WHICH THE BICENTRIC BIT CAN PASS. B.- BIT MAX DIAMETER. D.- D DRILLING DIAMETER DETERMINE THE HOLE FINAL DIAMETER C.-
- 189. DRILLING WITH A BICENTRIC BIT TRIPPING IN CASING DRILLING CASING DIAMETR/PASS THRU DRILLING DIAMETER PILOT DIAMETER WELL CENTER BIT CENTER BIT CENTER
- 190. BICENTRIC BIT RECOMMENDATIONS 1.- NEED SAME ATTENTIONAS A PDC BIT. 2.- NO ROTATION INSIDE CASING SMALLER THAN THE BIT ALLOWS. 3.- CONTROLLED DRILLING ( 1-2 MIN/M). 4.- “DRILL & OPEN” SIMULATANEOUSLY. THEY ARE NOT HOLE OPENERS. 5.- DO NOT PLACE A STABILIZER CLOSE TO THE BIT. 6.- HYDRAULICS IN ACCORDANCE WITH THE BIIGGEST DIAMETER.
- 191. OPERATING PROCEDURE THE FOLLOWING GENERAL PROCEDURE MUST BE OBSERVED TO AVOID DAMAGING BICENTRIC BITS PRIOR TO BREAKING-IN HAVING IN MIND ACHIEVING MAXIMUM PERFORMANCE.
- 192. OPERATING PROCEDURE ¡ WELLBORE PREPERATION ¡ IT IS VERY IMPOLRTANT TO EVAULATE WEAR AND TEAR OF PRIOR BITS TO DETERMMINE: ¡ JUNK DAMAGE, LOSS OF CUTTERS/TEETH/GAUGE. ¡ PERFORM A CLEANING TRIP IF NECESSARY. ¡ IF ACCESSORIES NEED BE RUN WITH FIXED BIT, ENSURE THAT CASING FLOATING EQUIPMENT ARE ADEQUATE. ¡ BIT PREPERATION. ¡ USE A RUBBER/WOOD MAT WEHN MAKING UP THE BIT. ¡ INSPECT CUTIING STRUCTURE TO DETERMINE PREMATIURE DAMAGE. ¡ INSPECT INSIDE OF THE BIT FOR EXTERNAL OBJECTS. ¡ VERIFY BIT MARKING AS PER API STANDARDS. ¡ VERIFY NOZZELS ARE FIRMLY SET AND OF THE PROPER TYPE AS PER BIT MARKING.
- 193. OPERATING PROCEDURE ¡ BIT MAKE UP ¡ HANDLE WITH CARE, USE A WOOD OR RUBBER MAT. ¡ ADJUST MAKE UP TONGS. USE AS PER TYPE, SIZE AND SPECS. NEVER USEDCASTING TOOLS. ¡ CLEAN AND LUBRICATE CONNECTION ¡ CAREFULLY RUN THE STRING AND ALIGN CONNECTIONS. ¡ MAKE UP BIT AND BASKET APPLYING RECOMMENDED TORQUE. ¡ TRIPPING IN HOLE ¡ REMOVE MAKE UP TOOLS, AND CAREFULLY RUN THE BIT THRU RT. ¡ WHEN PASSING THRU & BOPS , SHOES, TOL, USE A 2M/MIN RUNNING SPEED. ¡ ATTENTION TO DRAG POINTS NOTED IN PREVIOUS TRIPS. ¡ IF REAMING IS NEEDED USE WOB OF 0.5T & 35 RPM. EL USE OF OTHER HIGHER CONDITIONS MAY DAMAGER THE BIT CUTTING STRUCTURE AND BEARING REMEMBER: THESE BITS ARE NOT FOR REAMING.
- 194. OPERATING PROCEDURE ¡ TRIPPING TO BOTTOM ¡ CAREFULLY TRIP IN THRU DOGLEGS, TIGHT HOLES & OTHER SEVERITIES ¡ AMPLY CIRCULATE & ROTATE AT 40-60RPM FOR THE LA.ST THREE OFF BOTTOM METERS ¡ TAG BOTTOM CAREFULLY , VERIFY THE WEIGHT & TORQUE INDICATORS. ¡ PICK UP 0.5 M OFF BOTTOM ¡ CIRCULATE 5-10 MINS PRIOR TO BIT BREAK IN TO PREPARE THE new WELLBORE PATTERN. ¡ BOTTOM HOLE PREPERATION. ¡ SLACK OFF BIT WITH AMPLE CIRCULATION RATE. ¡ ESTABLISH THE NEW DRILLING PATTERN BY APPLYING 40-60 RPM & 1-2 T WOB. ¡ VERIFY& RECORD SPM & PUMP PRESSURE. ¡ START DRILLING WITH ABOVE PARAMETERS FOR 1M. ¡ INCREASE WOB IN 1 T STEPS UNTIL REACHING DESIRED WOB. ¡ INCREASE RPM TO DESIRED VALUE.
- 195. OPERATING PROCEDURE ¡ DRILLING ¡ ESTABLISH CORROSIVE INTERVAL CORRELATIONS, REDUCE RPM TO AVOID PREMATURE CUTTING STURCTURE DAMAGE . IN CASE OF FIXED CUTTER BITS, INCREASE FLOWRATE AND DECREASE WOB. ¡ PERFORM DIRLLABILITY TESTS REPEATEDLY TO STABLISH A CONSTANT ROP PATTERN. USE OF CONSTANT RPN & WOB THRU A GIVEN FORMATION TYPE MAY CAUSE PREMATURE BIT DAMAGE. ¡ DRILLING. ¡ UPON MAKING A CONNECTION: ¡ START PUMPING AT DESIRTED FLOWRATE IN INCREMENTS OF 20 SPM. VERIFY AND RECORD PUMP PRESSURE. ¡ TAG BOTTOM THEN AT 0.5 M OOFF BOTTOM CIRRCULATE AT FULL FLOWRATE FOR 5-10MIN. ¡ RESUME DRILLING AS INDICATED IN INITIAL PREPERATIONS. ¡ NEVER IMPACT BIT ON BOTTOM WITH ALL STRING WEIGTH .
- 196. OPERATING PROCEDURE ¡ TRPPING OFF BOTTOM ¡ AT END OF BIT LIFE: ¡ CIRCULATE WITH FULLFLOWRATE FOR 2-4 HOURS. ¡ PICK UP BIT OFF BOTTOM, WATCH FOR DRAG/OVERPULL. NOTE SUDDEN CHANGE INWEIGHT TO AVID TIGHT HOLES. ¡ DECREASE PULL OUT SPEED WHEN PASSING THRU RESTRICTIONSM TOL & BOPS. ¡ DISCONNECT BIT AS PER PROCEDURES FOR MAKE UP. ¡ WEAR TEAR EVALUATION. ¡ SET BIT WITH CUTTING STRUCTURE LOKKIUNG UPWARDS. ¡ WASH BIT TO REMOVE ALL ADHERED MATERIALS.NEVER IMPACT PIT TO ELIMINATE CUTTINGS OR OTHER MATERIALS. ¡ EVALUATE WEAR & TEAR AS PER THE 7 DIGIOTES CODE. AT TKEEP IN MINDE THAT THIS IS THE ONLY INDICATION YOU HAVE FROM THE BOTTOM OF THE WELLBORE. ¡ SELECT THE NEXT BIT TYPE AS PER WEAR AND TEAR AND FORMATIONTYPE.
- 197. OPERATING PROCEDURE API CONNECTIONS & MAKE UP TORQUE BIT DIAMETER (in) API CONNECTION (in) RECOMMENDED Torque (ft-lb) 3 ¾-4 ½ 2 3/8 Reg 1800-3085 4 5/8-5 2 7/8 Reg 3075-4650 5 1/8-7 3/8 3 ½ Reg 5175-7660 7 5/8-9 4 ½ Reg 12450-17750 9 ½-14 ½ 6 5/8 Reg 37100-38500 14 ½-26 7 5/8 Reg 48300-60900