x &y G BULL DIO 73 0732290 0003307 2 r API BUL D10 Second Edition August 1973 PROCEDURE For SELECTING ROTARY DRILLING EQUIPMENT OFFICIAL PUBLICATION REG US, PATENT OFFICE AMERICAN PETROLEUM INSTITUTE[.]
x- &y-G B U L L DIO-73 0732290 0003307 API BUL D10 Second Edition August 1973 PROCEDURE For SELECTING ROTARY DRILLING EQUIPMENT OFFICIAL PUBLICATION REG US, PATENT OFFICE AMERICANPETROLEUMINSTITUTE Washington, D.C 20006 Issued by AMERICANPETROLEUMINSTITUTE Division of Production 300 Corrigan Tower Building Dallas Texas 75201 r `,,-`-`,,`,,`,`,,` - Copyright American Petroleum Institute Provided by IHS under license with API No reproduction or networking permitted without license from IHS Not for Resale r BULL DLO-73 g 0732290 0003308 r PROCEDURE FOR SELECTING ROTARYDRILLINGEQUIPMENT becomes very important Since fewer bit changes are needed to drill soft formations, hoisting capacity is of lesser importance Drill-string torque and rotarytable horsepower are also much greater with increased rates of penetration into soft formations c Procedures outlined in the bulletin are divided into two categories, aims of which are: To provide a plan of analysis which will be useful in determining the performance capabilities of the several rig functions which are required forthe drilling of a specific well (Sections and ) To prescribe a means of testing, demonstrating, o r rating theperformance capability of the components of a specific rig (Sections and 4) d It is recognized that no existing rig will exactly fit the well requirements, and that compromise between the two will be necessary This recommendation w ill permitthose compromises tobe reached intelligently e It is also recognized that quality of supervision and rig personnel, and age andcondition of rig equipment are of great importance in selecting a rig These considerations are beyond the scope of this publication and are excluded from it FOREWORD a Thisbulletin (First Edition, Dec 1966) was prepared by a Subcommittee on Rating Capacity of Rotary Drilling Rigs, J E Hellinghausen, The Atlantic Refining Company, chairman, which functioned under the jurisdiction of the American Petroleum Institute’s Steering Committee on Drilling and Production Practice This edition supersedes the First Edition, was prepared by an ad hoc task group chaired by J E Hellinghausen, Atlantic Richfield Co., and was approved by the API Executive Committee on Drilling and Production Practice Its purpose is to describe a system of analysis which will a specific help to select a suitable rig for drilling well, avoiding use of a rig that is either too large or too small b This procedure presumes thatdepth ratings alone are not definitive, because wells in different areas requireemphasis on different rig functions For example, in drilling hard rock with frequent bit changes, hoisting capacity is of primary importance and hydraulic capacity needed to clean the bottom of the hole and circulate out cuttings is of lesser importance because of the low rate of penetration In drilling soft formations the penetration rateis often limited by the effectiveness of bottom-hole scavenging, and the hydraulic energy available at the bit `,,-`-`,,`,,`,`,,` - Requests for permission t o reproduce o r translate all 01’ any part of the material published herein should Copyright American Petroleum Institute Provided by IHS under license with API No reproduction or networking permitted without license from IHS I Not for Resale be addressed to the Director, Division of Production, Corrigan Tower Bldg., Dalla.s, Texas 75201 800 `,,-`-`,,`,,`,`,,` - Bulletin D10: Procedure for Selecting Rotary Drilling Equipment SECTION JOB RATINGTHEWELL To choose the best rig for drilling a particular well, it is necessary first to job rate the well Anticipated well depth, geologic conditions, casingplan, and otherdata influence drilling-rigrequirements, i l l assist and an analysis of the well or drilling planw materially in establishing rig needs (See p and 5.) A table, formulae, and graphs areincluded in Section to help in completing API Form No.D10-A, Drilling-plan Analysis.* Form No D10-A (see pages and 5) provides for severaldepth intervals(or hole sections) of the well with the lowermost depth of each section being the controlling depth in making calculations, Formation drillabilityusuallycan be classified as very soft,soft, medium, hard, or very hard Hole size, throughout theanalysis, is presumed to equal the diameter of the bit used in drilling the hole Drill-collar weight, corrected for buoyancy, should at least equal the bit weight desired for the hole being drilled The inside dia-meter of the drill pipe and the bore of the drill collars significantly affect the fluid pressure drop and hence the hydraulic horsepower spent inside the drill string This loss inside the drill string may be minimized through use of drill strings of largeinternaldiameterin combination withmoderatecirculation rates (SeeFig 1, 2, 8, and 9.) In the hoisting analysis, buoyancy is assumed to be offset by hole friction and may be disregarded The desired safe workingcapacity of the derrick ordinarily is a function of the maximum anticipated hook load and the number of lines strung; but under certain conditions, consideration must be given instead to the parting strengthsof drill-pipe o r casing strings Dynamic braking requirements, if critical, should be determined and specified on Form No D10-A, Drilling-plan Analysis *API Form No D10-A, Drilling-plan Anabsis (Pages and ) , are available in pads of 60 sheets a t $1.00 per pad fromAPI Division of Production, 300 CorriganTowerBuilding,Dallas,Texas 76201 Forms illustrated in Section herein are also available in pads of 60 sheets a t $1.00 per pad Copyright American Petroleum Institute Provided by IHS under license with API No reproduction or networking permitted without license from IHS All graphs in Section 2, relating to the hydraulic section of the analysis, are based on a mud density of 10 lb/gal (75 lb/cu f t ) , Corrected pressure losses (alsohydraulic horsepower) for mud of densities other than these, may be readily calculated since relationships between friction head and density are essentially linear Numerical values presented on the graphs are essentially the same as those in common use The amount of hydraulic energy which can be usefully employed in the removal of cuttings from under the bit cannot be predicted accurately, since not all the factors that influence such needs have been evaluated Currently, it is general practice to make an empirical approach to bit hydraulic needs by relating them to hole cross-sectional areasin amounts ranging from or bit hydraulic horsepower per square inch of hole area in the slowest of hard-rock drilling, to asmuch as or BHHP/sq in in soft-formation drilling (see Fig 4) Pressure losses in the annulus are minor when considered only from the standpoint of energy consumed, but may becomeof major concern if loss of circulation is probable This is true, in deep wells particularly, where formations are weak and where heavy muds are required Rapid pipe movements also may contribute to loss of circulation since such movements produce significant down-hole pressure surges, which increasewith length of pipe immersed In areas where running-in rates of either the drill string or the casing must be restricted, the reduced velocity should bespecified on Form No.D10-A, Drillingplan Analysis In thecompletion of the Drilling-plan Analysis, reasonable rig-performance capabilities for each of the several hole sections will be determined However, the rig chosen for drilling the well may require accepting, for the sakeof economy, less than preferred capabilities for some sections of the hole Ordinarily, concessions in this respect should take into account rig days rather than the footage involved Not for Resale Institute Petroleum American API FORM NO D10-A* DRILLING-PLAN ANALYSIS Lease Name & Well No County or P a r i s L S t a t - API Well No Projected Total Deptk" _, Field or Area `,,-`-`,,`,,`,`,,` - Geological Formation TD Hook horsepower at maximum wei *API Form No D10-A, Drilling-plan Anabsis (Pages and 21, are available in pads of 60 sheets at $1.00 per pad from API Division of Production 300 CorriganTowerBuilding,Dallas,Texas 76201 Copyright American Petroleum Institute Provided by IHS under license with API No reproduction or networking permitted without license from IHS Not for Resale Bulletin DIO: Procedure for Selecting Rotary Drilling Equipment API Form No DIO-A Drilling-plan Analysis API Well No Lease Name & Well No -Continued HYDRAULIC NEEDS Drilling fluid, type Density, Ib/gal, lb/cuf t Buoyancy factor Bit hydraulic horsepower, selected Annular velocity, selected, ft/min cal/min Circulation rate I Nozzle velocity, ft/sec Pressure losses (nominal) surface equipment, psi Through drill pipe, psi Through drill collars.Dsi Across bit nozzles, psi Drill-collar hole annulus, psi Drill-DiDe hole annulus, Dsi Total pressure loss, nominal, psi I Surface pressure, corrected, psi Hydraulic horsepowerat surface I I `,,-`-`,,`,,`,`,,` - ment I I I I I I I I l I I I , I I l MISCELLANEOUS Copyright American Petroleum Institute Provided by IHS under license with API No reproduction or networking permitted without license from IHS l I ROTARY NEEDS Rotary drive, type Table bore, in Static load capacity, M lb Rpm range, wax-min Torque capacity,ft-lb Rotary horsepower AUXILIARY EQUIPMENT Blowout preventers, class Size, through bore, in Stack Closing unit, accumulator capacity, gal-psi Number control outlets Number control stations Choke manifold, size/class Not for Resale - B U L L DIO-73 Petroleum 107315'290 0003312 b Institute American SECTION TABLE, FORMULAE, AND GRAPHS TABLE CIRCULATION RATE (Gal/min) Hole Drill-pipe Size, In Size, In %._ 14 13 12 11 10 16 17 16 Annular Velocity, &/min 40 60 60 70 80 100 90 14 12 21 11 28 28 36 29 41 36 48 41 66 47 62 62 69 68 76 64 83 70 90 16 91 82 104 81 10 19 16 29 24 38 32 48 40 61 47 61 66 76 63 86 I1 96 79 106 81 114 96 124 103 134 111 143 119 11 21 18 32 21 43 86 64 46 64 66 76 64 86 13 96 82 107 91 118 100 129 109 139 118 160 121 161 136 10 19 29 39 48 68 68 I8 81 97 107 116 126 136 146 10 21 81 41 62 62 72 82 93 103 113 124 134 144 166 11 22 33 44 66 66 77 88 98 109 120 131 142 163 164 14 27 41 64 68 82 96 109 122 186 160 163 177 190 204 19 16 37 31 66 46 16 62 94 71 112 98 131 108 160 124 169 139 181 166 206 170 226 186 243 201 262 216 281 232 20 11 41 34 61 61 81 68 102 86 122 102 142 119 162 136 188 168 203 110 223 187 244 204 264 222 284 239 306 266 24 20 47 41 71 61 94 81 118 102 142 122 166 142 189 163 213 183 236 204 260 224 283 244 301 266 831 286 364 806 24 21 49 42 73 64 98 86 122 106 147 121 111 149 196 170 220 191 246 212 269 233 294 266 318 276 343 291 367 318 26 22 20 61 44 40 76 66 60 101 88 81 127 110 101 162 133 121 171 166 141 203 111 161 228 199 181 264 221 202 219 243 222 304 266 242 330 281 262 366 309 282 380 331 302 26 23 21 62 46 42 79 69 63 106 92 84 131 116 106 167 138 126 184 161 147 210 184 163 236 201 189 262 230 210 289 263 231 316 276 262 341 299 273 367 322 296 394 346 316 26 23 60 46 74 69 99 91 124 114 149 137 174 160 198 183 223 206 248 228 213 261 297 214 322 291 347 320 372 843 32 30 27 63 69 96 89 82 126 118 110 168 148 131 189 178 166 221 201 192 262 231 220 284 266 247 316 296 214 347 326 802 978 866 829 410 386 361 441 414 384 473 444 412 88 86 34 76 72 61 113 108 101 161 148 186 189 119 169 221 216 202 266 261 286 802 287 210 840 323 803 378 369 331 416 394 311 464 430 406 491 466 438 629 602 472 538 606 41 39 37 82 78 74 123 118 111 164 161 148 206 196 186 247 236 222 288 214 269 829 818 296 370 868 388 411 392 870 462 431 401 493 410 444 634 609 481 648 618 63 61 49 43 106 102 98 81 169 163 141 130 212 204 196 118 266 265 244 216 818 306 293 260 811 367 342 303 424 408 391 347 471 469 440 390 630 610 489 433 583 661 638 47 636 612 687 620 689 663 636 663 741 114 684 606 794 69 66 69 138 134 130 118 201 201 194 178 216 268 269 237 344 836 324 296 418 402 389 366 482 469 464 416 661 636 618 414 620 602 683 633 639 669 648 692 768 136 713 662 826 803 718 711 896 810 842 170 964 931 907 829 1,033 1,004 912 888 84 79 14 167 169 148 261 238 222 334 318 29 418 897 869 601 477 448 666 686 617 668 636 691 762 716 666 886 796 739 919 814 818 1,002 963 881 1,086 1,033 961 1.170 1,112 1,035 1,263 1,192 1,103 117 113 1o7 238 226 214 360 388 321 461 460 428 683 663 636 IO0 642 811 788 749 933 901 866 1,060 1,018 963 1,161 1,126 1,010 1,284 1,239 1,111 1,400 1,361 1,286 1,611 1,464 1,392 1,634 1,616 1,499 1,760 1,689 1,606 263 268 268 8,868 636 627 616 3,611 803 790 714 8,363 1.070 1,064 1.032 3,096 1,338 1,317 1.289 2,831 2,619 1,878 1.844 2,321 li806 2,140 2,108 2,063 2,408 2,311 2,676 2,636 2,943 2,898 3,211 3,162 3,478 3,426 3,746 3,638 4,013 3,962 i0 30 20 66 61 4% Copyright American Petroleum Institute Provided by IHS under license with API No reproduction or networking permitted without license from IHS 616 ' Not for Resale 140 110 130 120 16; `,,-`-`,,`,,`,`,,` - 676 661 611 683 666 766 733 660 `,,-`-`,,`,,`,`,,` - TABLE (Continued) CIRCULATION RATE (Gal/min) 2928272162524232221201918 30 31 32 Annular Velocity, Ft/min Hole Drill-pipe Size, In Size, In 4% i 300 290 '280 1270 6260 0260 240 230 220 210 200 190 180 170 110 93 111 99 124 106 181 111 138 111 146 122 162 128 169 134 166 140 173 146 180 162 186 167 193 163 200 169 207 176 163 127 162 134 172 142 181 160 191 168 200 166 210 114 219 182 229 190 238 198 248 206 267 214 267 222 277 229 286 237 171 146 182 164 193 164 203 173 214 132 226 191 236 200 246 209 261 218 268 227 278 236 289 246 300 264 311 263 321 273 165 166 174 184 194 203 213 223 233 242 262 262 211 281 291 166 176 186 196 206 216 227 237 241 268 268 278 239 299 309 176 186 197 208 219 230 241 262 263 273 284 296 306 317 328 217 231 246 268 212 286 299 313 326 340 363 367 381 394 408 300 247 318 263 337 278 366 294 374 309 393 326 412 340 431 366 449 371 468 386 487 402 606 411 624 433 643 448 662 464 326 273 346 290 366 307 386 324 406 341 426 368 447 376 467 392 487 409 608 426 628 443 648 460 669 477 689 494 609 611 378 326 402 346 426 366 449 337 472 401 496 427 620 448 643 468 667 489 690 609 614 629 638 660 661 610 686 690 709 611 392 339 416 361 441 882 466 403 490 424 614 446 639 467 668 438 688 609 612 630 636 652 661 613 686 694 710 616 734 636 406 363 322 431 316 343 466 398 363 482 420 383 601 442 403 632 464 423 668 486 443 683 608 463 608 630 484 634 662 604 669 674 624 686 696 644 710 618 664 136 641 684 761 663 606 420 368 331 446 891 368 472 414 379 499 431 400 626 460 421 661 482 442 671 604 628 484 630 606 666 674 626 682 697 641 708 620 668 736 643 689 761 606 463 610 787 689 631 397 366 421 388 446 411 471 434 496 461 621 480 646 603 670 696 648 620 671 644 694 669 617 694 640 719 663 744 686 604 413 489 636 603 467 667 633 494 699 662 621 630 692 649 662 621 694 661 604 726 680 631 761 676 I10 669 I88 740 686 820 769 714 861 799 741 883 828 768 914 868 196 946 883 823 606 674 639 643 610 673 680 646 607 118 681 641 166 117 674 794 763 108 832 789 742 869 826 776 907 861 809 946 896 843 983 932 871 1,021 968 910 1,068 1,004 944 1,096 1,040 978 1,184 1,076 1,012 668 627 692 699 666 629 740 706 666 781 744 103 822 783 741 863 823 778 904 862 816 946 901 862 987 940 889 1,028 979 926 1,069 1,018 963 1,110 1,068 1,000 1,161 1,097 1,037 1,192 1,136 1.074 1,283 1,176 1,111 841 316 782 693 900 867 831 736 963 918 880 780 1,006 969 929 823 1,069 1,021 973 866 1,112 1.072 1,027 910 1,166 1,123 1.076 963 1,218 1.174 1,124 096 1,271 1,226 1,173 1,040 1,324 1,276 1,222 1,083 1,377 1.321 1,211 1,126 1,430 1,378 1,320 1,170 1,483 1,429 1,369 1,213 1,636 1,480 1,418 1,266 1,639 1,531 1,466 1,300 1,102 1,071 1,037 948 1,171 1,138 1,102 1,007 1,240 1,206 1,166 1,066 1,309 1,272 1,231 1,126 1,377 1,339 1,296 1,186 1,446 1,406 1,861 1,244 1,616 1,473 1,426 1,303 1,684 1,640 1,490 1,362 1,663 1,606 1,666 1,422 1,722 1.673 1,620 1,481 1,791 1,740 1,686 1,640 1,860 1,807 1,749 1,600 1,928 1,874 1,814 1,663 1,997 1,941 1.879 1,718 2,066 2,008 1,944 1.777 1,337 1,271 1,182 1,420 1,361 1,266 1,604 1,430 1,830 1,687 1,610 1,404 1,671 1,689 1,478 1,764 1,669 1,662 1,888 1,748 1,626 1,921 1,828 1,700 2,006 1,007 1,773 2,088 1,986 1,847 2,172 2,066 1,921 2,266 2,146 1,996 2,339 2,226 2,069 2,423 2,304 2,143 2,606 2,384 2.217 1.867 1,802 1,713 1,984 1,914 1,820 2,100 2,021 1,927 2,217 2,140 2,034 2.334 2,252 2.141 2,460 2,366 2,248 2,667 2,477 2,366 2,684 2,690 2,462 2,800 2.703 2,669 2,917 2,816 2.676 3,034 2,928 2,183 3,161 3.040 2,890 3.267 3,163 2,997 3,384 3,266 3,104 3,601 3,878 3,211 4,281 4,216 4.126 4,648 4,479 4,884 4.816 4,742 4,642 6,083 6.006 4,900 6,361 6,269 6,168 6,618 6,633 6,416 6,886 6,796 6,674 6,164 6,932 6,421 6.689 6.323 6;687 &190 6,447 6,966 6,860 6,706 7,224 7,114 6,968 7,491 7.377 7,221 7,769 7,640 7,479 8,026 7,904 7.737 Copyright American Petroleum Institute Provided by IHS under license with API No reproduction or networking permitted without license from IHS 626 6,060 Not for Resale 661 666 -~ BULL DLO-73 a 0732290 0003334 O r American Petroleum Institute Hydraulic horsepower: FORMULAE Buoyancy: Weight in mud = weight in air factor (See Fig 1) Wherein: specific gravity, mud specific gravity, metal GPM = gallmin AP = pressure difference, psi Pressure loss, correction for mud density: Drill collars, round, weight in air: W = 2.67 (D'-d') (See Fig 2) Wherein: APO = pressure loss, corrected AP = pressure loss, 10 lb/gal mud (or 76 lb/cu f t ) D = actual mud density, lb/gal (or lb/cu ft) Rotary horseaower : H P = -2n= T- N TN Wherein: W = weight, lb/lineal foot D = outside diameter, in d = ID or Bore, in Specific gravity of steel = 7.857 Hook horsepower, hoisting: HP = x 33,000 v (See Fig 3) Wheysin: W h = hook load, lb = load velocity, ft/min Average specific gravity of aluminum drill pipe with steel tool joints = 3.66 V DENSITY OF DRILLINGFLUID Copyright American Petroleum Institute Provided by IHS under license with API No reproduction or networking permitted without license from IHS 5,250 Wherein: T = torque, ft-lb N = table revolutions per minute 35,000 `,,-`-`,,`,,`,`,,` - BF=1- X buoyancy Not for Resale POUNDS PER GUBlC FOOT BULL DIO-73 Bulletin D10: Procedure for Selecting Rotary Drilling Equipment `,,-`-`,,`,,`,`,,` - FIG -DRILL-COLLAR Copyright American Petroleum Institute Provided by IHS under license with API No reproduction or networking permitted without license from IHS WEIGHTS, LB/ET IN AIR HOOK LOAD IN THOUSANDS OF POUNDS FIG 3-HOOK HORSEPOWER Not for Resale FOR HOISTING c 0732290 0003335 ~ ~" BULL DIO-73 10 0732290 0003316 American Petroleum Institute ,500 3 2n400 > S ~ 0 E 200 I O0 FIG 4- BIT HYDRAULIC NEEDS, AS A FUNCZION OF CIRCULATIONRATE, GPM FIG -JET-BIT HYDRAULIC FACTORS `,,-`-`,,`,,`,`,,` - Copyright American Petroleum Institute Provided by IHS under license with API No reproduction or networking permitted without license from IHS Not for Resale HOLE SIZE 16 American Petroleum Institute SECTION RATING OF THERIG’S SEVERAL COMPONENTS Many individual rig components which are not readily subject to non-destructive performance tests are covered already by API specifications and ratings In many instances, the only ratings for equipment are the manufacturers’ recommended capacities In general, these have been found to be reliable and possibly on the conservative side This applies particulariy to the rated capacity of various items of suspension equipment Performance capabilities of certain other rig components, however, are readily subject demonstrable to tests asprescribed in theschedules included herewith, D10-B, Rig-rating Check List, sample of which and which can be summarized on APIForm No D10-B, Rig-rating Check List, sample of which follo~vs API FORM NO D10-B* RIG-RATING CHECK LIST Rig Owner Rig Identification Intended Area of Rig Use Data Submitted by: Date A CAPACITY FOR HANDLING CASING OR DRILL PIPE (From Form No D10-C, Schedule A) lb B SUBSTRUCTURE LOAD-SUPPORTING CAPACITY: (From Form No D10-C, Schedule B) Maximum pipe setbackcapacity L b L Maximum rotary-table supporting capacity, irrespective of setbackload Corner loading capacity (for derricks only) b lb C HOISTING AND BRAKING CAPABILITIES (From Form No D10-D, Schedule C) Hook H P Hook Velocity Hook Load L lb Observed performance hoisting Auxiliary brake performance load M lb hook Max D.MUD PUMP PERFORMANCE CAPABIIATY (OBSERVED) (From Form No D10-E, Schedule D) High-volume Service h ’ gal/min HHP d t / m i n _ft/min High-pressure Service h I gal/& HHP psi \ psi Main pump Stand-by Stand-by E ROTARY-TABLE PERFORMANCE Continuous Rotating Speed Range: Rotary table: Make 4PI Opening Model `,,-`-`,,`,,`,`,,` - Independently driven table, max RPM to Copyright American Petroleum Institute Provided by IHS under license with API No reproduction or networking permitted without license from IHS *API Form No DlO-B, Rig-rating ~~ P1d&ion foravailable Resale Check List (Pages 1-3),Not are in pads of 300 Corrigan Tower Building Dallas, Texas 76201 -:x ~ RPM 60 sheets at $1.00 per pad from API Division of - Bulletin D10: Procedure for Selecting Rotary Drilling Equipment Independent drive unit, make Drive engine unit, 17 Model or motor: Make Model Cont HP rating Table driven through dramworks: Ratio P M Ratio I T P t o d P M Ratio I I T P M to RPM Mt o R P M Ratio I V L P M to” RPM F DRILL-STRING SPECIFICATIONS Drill Pipe String: Nominal size APIgrade in lb Tool-joint size and style Tool-joint OD Length of string Date of last inspection ft `,,-`-`,,`,,`,`,,` - foot Weight per #2 #1 in No of joints by inspection Inspection method CLASS* PREMIUM Other drill-pipe condition information, such as hardbanding, protectors, etc: Copyright American Petroleum Institute Provided by IHSfor underinspections license with APIandclassification *Details of used drill pipeare included inSection NoLreproduction license fromof IHS Production, 300 CorriganTower Not forBuilding, Resale i m ~ t a - aorvnetworking a i l n b ~ epermitted _ f p e Awithout P I Division /- M I RP TG: Drill S t m Design and Operating DaJas, Texas 76201 B U L L DIO-73 Petroleum 18 Drill Collars Quantity American 07321230 0003324 aT Institute Max OD (to nearest l / í in.) Min bore (to nearest 1/16in.) Averagelength Approx string weight Tool-joint styleandsize , , G AUXILIARY EQUIPMENT Mud Tanks Capacity Number Size Mud-mixing Equipment a Pumps Number Make Type Size b Prime Mover Model Number HP Make Mud-agitating Equipment- Describe: Make Shale Shaker: Desander: Make Model `,,-`-`,,`,,`,`,,` - Copyright American Petroleum Institute Provided by IHS under license with API No reproduction or networking permitted without license from IHS Model Not for Resale Capacity, gal/ Bulletin D10: Procedure for Selecting Rotary Drilling Equipment PumpDesander Make : Prime Model Desander-pump Make 19 Capacity, gal/ Type Mover: HP Well-control Equipment Blowout Preventers No Make API Flange Size Model Bore Working Pressure Choke Manifold-Describe: Kelly Cock: Make Model Drill-pipe Make Safety Valve: Degasser: Model Make Model Mud-Gas Separator - Describe: Blowout Preventer Closing Unit Make No of No of M o d e L O u t l e t n S t a t i o n s Accumulator volume (liquid and gas) gal Precharge sure Final `,,-`-`,,`,,`,`,,` - Copyright American Petroleum Institute Provided by IHS under license with API No reproduction or networking permitted without license from IHS Reducing and regulating valve ? Y e s N o Not for Resale Institute 20 Petroleum Generators Number Model American Make Capacity, KW Type Generator Prime Mover Model Number Make HP `,,-`-`,,`,,`,`,,` - Lighting System Vapor Proof: Y e s h T o Mud Storage -Describe: Cement Storage Capacity: Fresh-waterStorage Capacity: Fuel Storage Capacity: Additional Equipment -Describe: Copyright American Petroleum Institute Provided by IHS under license with API No reproduction or networking permitted without license from IHS Not for Resale Bulletin D10: Procedure för Selecting Rotary Drilling Equipment 21 API FORM NO D10-C* SCHEDULE A CAPACITY FOR HANDLING CASING OR DRILL PIPE Hook-load capacity of any piece of equipment in the hoisting system is defined as that load in pounds that may be suspended by the höök which will load the particular piece of equipment up to its API or manufacturer's rated capacity Hook-load capacity of the rig is therefore limited by that equipment having the least such capacity These data apply to the following rig: Rig identification:" Rig hook-load capacity, for drill string i by s Rig hook-load capacity, running casing i b , as limited below (weakest link) I n b , as limited by below Mast or Derrick Rating Wind resistance with no drill-pipe setback -~ Wind resistance w capacity Racking i t u mPh A -in drill pipe of - t of drill-pipe setback i - Static hook-load capacity (with t lines strung traveling to block) M lb I (1) Make Traveling block (2) Weight tons (3) No of Sheaves (2) Weight (1) Make tons (3) No of Sheaves Elevator links Drill-pipe elevators elevators Casing Rotary drilling line (hook-load capacity) Swivel Classification Size Grade *APIForm No D (SchedulesAand CorriganTowerBuilding,Dallas,Texas Center API breaking strength** factor B) is available in padsof 75201 Copyright American Petroleum Institute for **Breaking strength (nominal) nem wireropes are shown in Provided by IHS under license with API Division ofProduction, 300 CorriganTowerBuilding,Dallas,Texas No reproduction or networking permitted without license from IHS Safety tons tons tons tons M lb No Lines 50 sheets at $1.00 perpadfrom API DivisionofProduction, API Spec 9A: Specification jw V i r e Rope availablefrom 75201 Not for Resale 300 API `,,-`-`,,`,,`,`,,` - Crown block American Petroleum Institute 22 API FORM NO D10-C* SCHEDULE B SUBSTRUCTURE LOAD-SUPPORTING CAPACITY Substructure: Make Model or type A t Width d t Length A t Floor height Height above ground to underside of rotary beams f t - n For use with derrick (or mast) having static hook load capacity of Maximum pipesetbackcapacity Maximum rotary-table supporting capacity irrespective of setback load Corner loadingcapacity (for derricks only) Loads imposed by tensioning devices Additional loads _Mlb _Mlb _Mlb M lb \ I lb of 60 sheets at $1.00 perpadfromAPIDivision of Production, 800 `,,-`-`,,`,,`,`,,` - 'API Form No D (SchedulesAand B)isavailableinpads Corrigan Tower Building, Dallas, Texas 76201 L lb Copyright American Petroleum Institute Provided by IHS under license with API No reproduction or networking permitted without license from IHS Not for Resale Bulletin DIO: Procedure for Selecting Rotary Drilling Equipment 23 API FORM NO D10-D* SCHEDULE C HOISTING AND BRAKING CAPABILlTIES Hook-horsepower rating and auxiliary brake capability are based on actual field performance, as measured by a standard test procedure By this test procedure, hook-horsepower andbraking capability are determined from observations made during trip- ping operations, whereby the speed of the middle single of a stand is combined with concurrent weightindicator reading The data submitted applies to the following rig: Rig identification: Maximum hook-horsepower observed to be as of a t hook load o at (Date) f b (Location) and observed by Rig equipped as follows: Equipment Description (Type, Make, Model, Size, etc.) Auxiliary brake Engine-hoist transmission system Drawworks Hoistingengines - Observed Test Data Hoisting Drawworks Ratio Hook Load, M lb Sec to Pull Middle Single Hook Velocity, Calculated Hook ftlmin Horsepower No, Linea strung Observed Auxiliary Brake Performance Hook Load, M lb Sec to Lower Middle Single Hook Velocity, ftlmin No of Lines to Traveling Block Remarks `,,-`-`,,`,,`,`,,` - Copyright American Petroleum Institute Provided by IHS under license with API No reproduction or networking permitted without license from IHS Not for Resale *API Form No D10-D (Schedule C) ia available in pads of 60 sheets at $1.00 per pad from API Division of Production, 300 Corrigan Tnwer Rnilrlinw Tlallna Texas 76201 Petroleum 24 American Institute API FORM NO D10-E* SCHEDULE D MUD PUMP PERFORMANCE CAPABILITY Mud pump ratings are to be based on hydraulic horsepower they are capable of delivering continuously duringnormaldnlling operations Hydraulic horsepower 1s determined in thefield by using stand- ard test procedures, whereby pressure-gage observations and eithermeasured or calculated mud volumes are used to calculate pump hydraulic horsepower output - Rig identification: (1) Main PumpSpeci5catiom (2) Stand-by (3) Stand-by Model designation Rated input horsepower Make (manufacturer) - Rated RPM X stroke length High Volume Service Conditions Liner sizes: Max.-min, Corresponding rated WP X i n High Pressure - X i n - X i n High Volume High Volume High Pressure High Pressure GPM displaced @ rated RPM Observed Performance `,,-`-`,,`,,`,`,,` - Dates tested Engines connected to mud p~mps"" Do the same engines drive rotary? Pump RPM duringtests Engine RPM during test Max no-load pump RPM Standpipe pressure, psi Liner sizes during tests GPM, measured GPM, calc @ "?hvol eff Pumpoutput, HHP *+Engines supplying power to mud pumps: No Make Manufacturer's' Continuous-duty Rating at Owner's Governed Speed Model HP @ R P -M Copyright American Petroleum Institute Provided by IHS under license with API No reproduction or networking permitted without license from IHS " " ~~ W Resale CAPI Form No D (ScheduleD) is available in pads Not offor50 sheets at $1.00 perpadfrom rigan To-r-Building Dallas, Texas 76201 P @ API DivisionofProduction, RPM 800 Cor- Bulletin Dio: Procedure for Selecting Rotary Drilling Equipment 25 SECTION RIG-RATING PARAMETERS SAFE LOAD RATINGS Manufacturers of derricks, masts, and substructures, in cooperation with API, furnish the users of such equipment with applicable safe load ratings If specified safe load ratings for given conditions are not exceeded, no failure is likely If these ratings are exceeded, failure is possible At greater overloads, failure is probable, and at some critical loading, failure is certain Derricks and Masts Derricks and masts are designed to a static hookload capacity when using a specified number of lines andwith 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 Substructures When substructuresare used withderricks and masts, refer to API Std QE: Specification f o r D d l i n g and Well ServicingStructures* API Std 4E provides, among other things, that substructures carry name plates bearing specified information including : Maximum pipe setback weight, pounds Maximum rotary-table loading, poundEventhough substructuresare designed to support these two loads “acting simultaneously”, it should never be presumed that capacity notutilized in one of the areas may be transferred, in whole or ir part, to the other area Each such rating is maximwr~ for its area irrespective of loading in the other area Wire Lines Nominal breaking strengths Eor new wire rope are shown in API Spec A : Specification f o r Wire Rope*, Tables 3.3 through 3.17 Loads and safety factors: When a wire rope is reeved over a number of sheaves in a block-andtackle system, the load on the fast line is greater than the total load divided by a number of parts of line, because of the loss caused by friction in the sheaves and in the bending of the rope around the sheaves The efficiency factor of various parts of line for roller-bearing sheaves has been established as follows (see Section G, Ref 65) : G parts of line, efficiency factor = 0.874 parts of line, efficiency factor = 0.841 10 parts of line, efficiency factor = 0.810 12 parts of line, efficiency factor = 0.770 *Available from API Division of Production, 300 Corrigan Tower Building,Dallas, Texas 76201 The maximum load on the fast line maybe determined from thefollowing formula: P = Wherein: P = load on fast line W = hook load, in pounds, including travelling block N = number of parts of line (lines strung to traveling block) E = efficiency factor DETERMINATION OF HOOK HORSEPOWER Hook horsepower may be determined during tripping operations by observing weight-indicator readings and timing with a stopwatch the hoisting of the middle singles of various stands and referring these values to Fig 14,Section This chart is based on the following standard equation, assuming the average length of a single to be 30 ft The weight-indicator reading includes the weight of the block and hook and any pipe drag Timing the middle single gives a steady condition and permits demonstration of maximum horsepower Because of the way in which governors affect engine performance, if it is desired to demonstrate the full horsepower of mechanical-drive internal-combustion engines it may be necessary to put the drawworks in the next higher gear several stands earlier than in usual operating practice to prevent the engines from coming up to governed speed This is not true fortorque-converter, electric, or steam drives The accuracy of the weight indicator may be checked from known values of equipment weight, weight of drill string, and mud buoyancy The accuracy of stopwatch observation can be expected to be the same for start and stop as the tool joints pass the reference point Altitude usually affects the maximum output of internal-combustion engines AUXILIARY BRAKES F o r the primary purpose of reducing substantially one item of rig-operating expense, many drawworks incorporate some form of auxiliary brake which permita the lowering of heavy hook loads safely at retardedrates without incurring appreciable brake maintenance Two general types of auxiliary brakes currently are in common use, viz: u, hydro-dynamic; `,,-`-`,,`,,`,`,,` - Copyright American Petroleum Institute Provided by IHS under license with API No reproduction or networking permitted without license from IHS W N X E Not for Resale BULL DIO-73 26 Petroleum American and b, eddy-current In both types, work is converted intoheat which then is dissipated through liquid cooling systems Auxiliary-brakecapabilities may be determined during tripping operations by observing weight-indicatorreadingsandtimingwith a stopwatch the lowering of the middle single of a stand while carrying the load exclusively with the auxiliary brake The operating principles employed are as follows Hydro-dynamic Brakes A hydro-dynamic brake is a hydraulic device that absorbs power by converting mechanical energy into heat Resistance is created exclusively by agitation of water circulated between the veined pockets of the rotorandstator elements, m t h the conversion of mechanical energyintoheattaking place directly within the water itself The amount of mechanical energy that can be absorbed in this manner is dependent u on the quantity and velocity of the water in the worbngchamber With any specific quantity of water in theworking chamber, the velocity of the water circulated is increased with increased revolving speed of the rotor, with resulting increase in fluid friction, In thismanner the torque capacity of a hydro-dynamic brake increases approximately in proportion to the square of the speed If the speed is doubled, the torque resistance is increased four times The revolving speed limitation of the rotor is mechanical, but the torque capacity of the brake increases with speed in the foregoing ratiouptothe maximum recommended safe operatingspeed for each size brake Copyright American Petroleum Institute Provided by IHS under license with API No reproduction or networking permitted without license from IHS Not for Resale p Institute The secondary function of the circulating system is to provide controls to permit the driller to vary the braking capacity to meet requirements The capacity at any speed is adjustable by regulating the quantity of water being circulatedbetween the veined pockets of therotorandstatorsinthe working chamber The circulating system includes means for dissipating heat Many factors must be considered in determining proper size of brake for specific operating conditions To simpjify selection of brakes, performance charts are available from the manufacturers of hydro-dynamic brakes Eddy-current Brakes An eddy-current brake is an electro-magnetic machine which includes primarily a driven element being an all-ironrotor,and a stationary member which provides a variable and controllable magnetic field in which the driven element revolves Magnetic forces, induced in the rotor, tend to oppose accelerated rotary movement Eddy currents, produced in the iron rotor as it is rotated within the electromagnetic field of the stator, generate heat which is transferred to a liquid medium circulating through the machine Thus mechanical energy is converted into heat and then is dissipated by a liquid cooling system Magnetic forces and eddy currentsinthe iron rotor increase with increases in intensity of the electro-magnetic field and, to a limited extent, with increases in thespeed of rotation Thestator’smagnetic field is produced by coils, separately excited from an extraneous source of direct-current electricity Within prescribed limits of the machine, regulation of the excitation current controls the relative counter torque or braking effect available at various rotational speeds of the rotor Performance data on machines of various capacities are available from manufacturers of eddy-current brakes `,,-`-`,,`,,`,`,,` - The primary function of the circulating system is to supply cool water through the inletof the brake to displace the heated water and thus prevent the formation of steam within the brake; also to remove the heated water from the circulatingsystem, 0732290 0003332 I Bulletin Dio: Procedure for Selecting Rotary Drilling Equipment 27 SECTION GLOSSARY HORSEPOWER (HP) : Force ( l b ) X speed ( f t / m i n ) 33,000 HYDRAULIC HORSEPOWER (HHP) : differential Circulation rate ( g p m ) x pressure(psi) 1,714 ELECTRICHORSEPOWER (EHP) : Kilowatts X 0.746 THERMALHORSEPOWER (THP) : Btu/min 42-42 INPUT HORSEPOWER: The horsepower that is put into an operatingsystem OUTPUTHORSEPOWER: The horsepower that is put out by an operatingsystem EFFICIENCY:Thepercentagerelation of outputto input MECHANICAL EFFICIENCY: Thepercentagerelation of mechanical power output to mechanical power input HYDRAULIC EFFICIENCY:The percentage relation of hydraulic horsepower output to mechanical horsepower input In some cases this may include mechanical efficiency, VOLUMETRIC EFFICIENCY: The percentage relationbetween the actual delivered capacity of a pump and the calculated displacement of the pump TRANSMISSION Loss: The difference between output homepower and input horsepower It may conveniently be expressed as percentage of input horsepower BRAKEHORSEPOWER (BHP) : The horsepower output of an engine os motor measurable by a special brake or a dynamometer BIT HYDRAULICHORSEPOWER (BHHP) : The hydraulic horsepowes equivalent of the gallons per minute and the pressuredrop across the bitnozzles x Psi = B H H p 1,714 BIT MECHANICAL HORSEPOWER: The horsepower required to rotate the bit only, not_ including that required to rotate the drill string contacting the walls Copyright American Petroleum Institute Provided by IHS under license with API No reproduction or networking permitted without license from IHS ROTARYHORSEPOWER (RHP) : The horsepower required to rotate the drill string and thebit TORQUE:The tangential force (pounds) times lever a n n length HOOKHORSEPOWER (HOISTING HORSEPOWER) : PUNPINPUT HORSEPOWER: Mechanical horsepower put into thepump PUMPOUTPUTHORSEPOWER: Hydraulic horsepower put outby pump ENGINEHORSEPOWER (ENGINERATING): Refer to A P I Std 7B-IIC This standard covers rating of internal combustion engines The MAXIMUM rating is not usable The INTERMITTENT rating is applicable to hoisting The CONTINUOUS rating is applicable to pumping BRAKING CAPACITY:The load which the drawworks brake and auxiliary brake can retard to a constant reasonable speed, o r hold DRILL PIPE: A portion of thedrillstring which transmits power to the bit DRILLCOLLAR: Thick-walled pipe to provide stiffness and concentration of weight at the bit DRILLSTRING: A combination of drill pipe, drill collars, and accessory components BIT PORT: A fluid-flow port in a bit JETNOZZLE:A fluid-flow port ina jet bit JET-TYPE BIT: A bit employing directed, rapid flow of fluid from a nozzle or nozzles DRILLINGHYDRAULICS: The employment of the science of the effects of fluid velocities and pressures and forces involved ROTARY DRILLING RIG: Includes prime movers, hoisting, rotating, circulating, and auxiliary equipment necessary for well drilling STEAM RIG: A rotary drilling rig with steamboilers and steam-driven equipment ALL-ELECTRIC RIG: A rotary dsilling rig using power from electric power line DIESEL-ELECTRIC OR GAS-ELECTRIC RIG: A rotary drilling rig using self-generated electric power MECHANICAL-ELECTRICRIG: A rotarydrilling rig using diesel or gas engines to drive pumps and generator MECHANICAL RIG: A rotary drilling rig driven by diesel or gasengines STRAIGHT MECHANICAL DRIVE : Internal-combustion engines connected to leads by clutches which can be slipped a moderate amount Not for Resale `,,-`-`,,`,,`,`,,` - Therate of doing work (transferringenergy) equivalent to lifting 33,000 lb ft/min (33,000 ftlb/min) This is also 550 ft-lb/sec Lifting a weight is a simple example of a force in motion The same combination of force-times-speed in any direction-along the flat, on a slant, around a cusve, or any combination-is the same horsepower (Also, othertransfers of energymay be stated as horsepower.) American Petroleum Institute 28 FLUID DRNE:Special pump-and-turbine unit connecting engine to load, permitting some slip and flexibility HYDRAULIC DRIVE: A motor driven hydraulically by a pump TORQUECONVERTER: Fluid drive which increases torque and reduces rpm REYNOLDS Nunism (R.): A dimensionless function that characterizes friction of fluid flow in pipes and is defined by the following: `,,-`-`,,`,,`,`,,` - Wherein: v = mean velocity, ft/sec d = diameter of pipe, f t p = density, Ib/cu f t N = absolute viscosity, lb/ft-sec = 0.000672 X viscosity in centipoise Copyright American Petroleum Institute Provided by IHS under license with API No reproduction or networking permitted without license from IHS Or,in oil-field engineering units : R = 928 (*) Wherein: v = mean velocity, ftlsec d, = diameter of pipe, in pl = density, lb/g?l N, = plastic wscoslty, cp or : Wherein: G = dl = pl = N, = Not for Resale flow rate, gal/min diameter of pipe, in density, lb/gal plastic viscosity, cp Bulletin Dio: Procedure for Selecting Rotary Drilling Equipment 29 SECTION BIBLIOGRAPHYFOR API COMMITTEEFORRATING `,,-`-`,,`,,`,`,,` - Modern Drilling Equipment, Rigs andEquipment, Petr Engr., July (1961) Moore, Preston L: How to Apply Hydraulic and Bit Horsepower, Oil Gas J., Jan 23 (1961) Stone, V D: High-speed Drilling techniques inSouthern Louisiana, API Drilling and Production Practice, 49 (1961) Hom Humble Plans for Minimum Drilling Costs, Oil Gas J., Sept 26 (1960) What Weight and Speed Produce Lowest Drilling Costs?, Oil Gas J., Mar (1960) Jersey Research Attacks Drilling Costs, Petr Engr., Oct (1960) 7.VariableWeight and Rotary Speed for Lowest Drilling Cost, AAODC paper, Sept (1960) Brantly, J E: Rotarg D d l i n g Handbook, Palmer Publications, New York, 1961, 6th Ed Peret, J W and Kastrop, J E: Guide to Jobrating Well for Minimum Rig Horsepower in Jet Bit Drilling, Petr Engr., 32, Oct (1960) Tablesestablish minimum horsepower requirements for pumping and hoisting 10 More FromDrillingRig Engines, OilGas J., Sept 26 (1960) 11 Williams, B G : Which Hoisting System is Better?, World Oil, 148 [2] Feb (1959) Load capacity of derrick, and design stresses of wire line 12 Stevenson, J M : Equipment Management - Key to Economical Operations, Petr Engr., (1959) 13 McGhee, E : Drawworks and Compounding Transmission, Oil Gas J., 56, 125, Oct (1958) Economy through right equipment selection 14 Hogwood, E E: Drillingfor Oil Electrically, WestinghouseEngr., 19 [Z] Mar (1959) Discussion of electric drive systems for drilling rigs 15 Marsee, J: Get the Most from Your Drawworks, Petr Engr., 31, B112, Mar (1959) Mechanical factors of drawworks rating 16 Crake, W S: LetsReturntoCentral Power Plants, Oil Gas J., 57, 40, Sept 28 (1959) Evaluation of necessary horsepower on electric rigs 17 Derricks, Mast, and Lines, OilGas J., 57, C16, Jan 29 (1959) 18 Rotary Rig Design; Panel Discussion, Oil Gas J., 57, 97, June 22 (1959) 19.API Std 7: Specification fop Rotaw Drilling Equipntent, American Petroleum Institute, Dallas, Mar 1965,20th Ed Copyright American Petroleum Institute Dimensional on drill stems, rotary Provided by IHS under licenserequirements with API No reproduction or networking permitted without license from IHS tables, shafting, chain and slush pumps OF ROTARYRIGS 20 Colebrook,R W: How to Get Most Hydraulic Power at Bottom of Drill StringinRotary Drilling, ASMEPaper No 58, PET-6, Sept (1958) Discussion of probable future mud-pump requirements 21 Lackey, M D: Proper Selection of Engine Compounds, WorldOil, 147 [S] Oct (1958) Factors forselection of proper compounds 22 Colebrook, R W : Maximum Horsepower Where it Counts, Petr Engr., Oct (1958) Affect Drilling 23 Moore, P L: Five Factors that Rate, Oil Ga.s J., Oct (1958) Mud PressuresIn24 Watson and Sullins:High crease Penetration, WorldOil, Jan (1958) 25 Lubinski, A: The Effects of Weight and Speed on Penetration, World Oil, Jan (1958) 26 Speer, J W: A Method of Determining Optimum D19ling Techniques, API Drilling and Production Practice, 130 (1958) ; also World Oil, Mal (1958) 27 Webb, G W: Diesel Rig Drives, Ddling Contractor, April (1957) 28 Carr, J R: New Designs in Offshore Drilling Rigs, Engr W 159, 54, Oct (1953) ;38, Oct 24 (1957) Description of advanced design and improvements of offshore rigs 29 LaFave, V A: Design Applications for Drilling Equipment, Petr Engr., 28, B138, Oct (1956) ; and Oil Ga.s J., 54, 113, Dec 17 (1956) 30 Keating, T W; Clift, W D and Cutrer, J: Hydraulics of Rotary Drilling, Petr Engr., 28, B38, April (1956) Practical optimum limits for hydraulic horsepower 31 Hohmann, H M and Busking, B E: How Inertia Affects Rig Hoisting, World Oil, 142, 132, Mar (1956) Evaluating specific phases of rig performance 32 Colebrook,R W: Hydraulic Couplings and Torque Converters in Big Rig Drives, Petr Engr., Oct (1956) Application to largerig drives, and mud pumps 33 Wardroup and Cannon: What Factors are Contributingto IncreasedDrillingRates, World Oil, May (1956) 34 Bobo and Hoch: Keys to Successful Competitive Drilling, World Oil, Nov (1957) 35 Buzzini, A P: Rig Selection, Petr Engr., Nov (1955) 36 Fredhold, A Jr: Crown andTraveling Blocks, Petr Engr., Dec (1955) 37 Walker, R L: What's Ahead in Rig Design? Oil Not for Resale Gas J., May 23 (1955) BULL DIO-73 0732290 000333b q American Petroleum Institute 30 38.Fairman, R B: Electricity Drives Offshore Rigs; Diesel-Electric Power System, OiE Gas J., 54, 94,July 16 (1966) 39.Fredhold, A Jr: Power Transmission, Petr Engr., 28, B28, Aug (1966) 40.Helder, J R: Design of a Slim Hole Rig, Petr Engr., Oct (1966) Design of rig requirements 41.Graham, G: Factors in Evaluating Drilling Rig, Oil Gas J., July (1965) Evaluation of machinery, well site, well program, etc `,,-`-`,,`,,`,`,,` - 42.Reichert, C T:RotaryDrilling Rigs, J Inst Petr., Nov (1954) Selection of suitable components for a drilling rig 43.Pedersen, J N: Drilling Equipment and Techniques, Petr Engr., Ref Ann (1964) 44.Goodrich, J D: Calculating Economical Hook Horsepower, Wodd Oil,Aug (1952) Graphs and formula showing rig hoisting characteristics 46.Hamaker, R G: Check Your Hydraulic System to Cut Your Drilling Costs, World Oil, Mar (1963) 46.Rose, W F: Drilling-Equipment Report, Oil Gas J., Sept 29 (1962) 47 Alcorn, C H: New Drilling Equipment, World Oil,Feb 16 (1963) 48.Cooper, M L: Torque Converters Supply Flexibility and Economy, World Oil, Nov (1962) 49 Payne, John M: Equipment and Techniques for 20,000-ft Drilling, Petr Engr., June (1950) 60 Oberg, C H : The Balanced Rotary Rig, AAODC, Sept (1949) 61 Craig, R W: Power Requirements for Rotarydrilling Operations, API Ddling and Production Practzce, 103 (1949) Copyright American Petroleum Institute 2with - 6API Egan Provided by IHS under251 license 1bI - permitted Egan No reproduction or networking without license from IHS 1b1, 4-70, Egan 1.6M 8-73 Egan Not for Resale 62.Payne, John M: A Study Group Investigation of Equipment and Techniques for 20,000-ft Drilling, API Ddling and Production Practice, 123 (1949) 63 D’Arcy, Nicholas A,, Jr: Application of Hydraulic Drives t o Oil Field Equipment, AAODC (1949) 54 Crake, W S: Application of I?te?nal Combustion Engine Power to Rotary Dnlllng Rigs, ASME (1947); also Petr Engr., Dec (1947) 66 Today’s Drilling Rigs, Oil Gas J., Oct (1948) 56.Mahan, Joseph R: Drilling Rigs for Deep Wells, ASME 1948 Paper No 48,PET-20 Analyzes loads encountered and power required 67 Livermore, George P :Mechanical Analysis of Size of Prime Movers for Rotary Drilling Rigs, Oil Weeklg, April 13 (1936) 68 Albrecht, A H: Electrical Power Application to Rotary Drilling, Proc Am Pet Inst., Sec IV (Prod Bul 208) 121 (1931) 59.Alcorn, C W:Electrical Power Application to Rotary Drilling, Proc Ant Pet Inst., Sec IV (Prod Bul 208) 1969 (1931) 60.Trax, David L and Hawkins, R R:*InternalCom bustion EnginesforRotary Drlllmg, Proc Am Pet Inst., Sec IV (Prod Bul 207) 122 (1931) 61.Gignoux, J R and March, R A: Equipment Correlation for Steam Rotary Drilling, Proc Am Pet Inst., Sec IV (Prod Bul 20.4) 80 (1929) 62.Dunvard, E Stanley: Power Rate Structure for Oil Fields, Oil Gas J., Sept (1929) 63.Jones, Wendell M: Choice of Equipment for Drilling Exploration Wells by the Rotary Method, Proc Am Pet Inst., Sec III (Prod Bul 203) 82 (1928) 64.Pigott, R J S: Mud Flow in Drilling, APZ Drilling and Production Practice, 91 (1941) 66.Wickwire Spencer, Div Colorado Fuel & Iron Corp: Oil Field Handbook withTon-Mile Tables