钻井数据手册fdgh
1 一、常用单位换算表 单位 公 英 制 换 算
压力
1兆帕(MPa)=10.2工程大气压(at)=103kPa=106Pa;
1bar=1kgf/cm2 1工程大气压(at)=14.7磅/英寸2(psi); 1磅/英寸2(psi)=0.0703kgf/cm2 长度 1英尺=12英寸 1英寸=25.4毫米 1英尺=0.3048米 1码=0.9144米 扭矩 1磅·英尺=0.138255公斤·米 1千克·米=9.8牛顿·米
流重 1美加仑/分=0.0631升/秒 1英尺3/分=0.472升/秒
质量 1吨=0.9842英吨=1.1032美吨=2205磅=1000kg 1磅=0.4536Kg 比重 1磅/英尺3=0.01602克/厘米3\ 1磅/美加仑=0.119826克/厘米3
温度 n℉=[(n-32)×5/9]℃
功率 1马力(hp)=735.499瓦(w) 1（KW）=1.36马力 1英马力=1.014马力 体积 1美桶=159升 1美加仑=3.785升 1尺3=28.32升
二、物质密度 水 泥 3.15 硝 酸 （100%）1.513 灰 岩 2.6-2.8 硫 酸 （100%）1.83 重晶石 4.0-4.5 盐 酸 （40%）1.20 铅 11.3-11.9 甘 油 1.26 砂岩 2.0-2.7 汞 13.6 酒精 0.79 硫化氢 0.00119 石油 0.85-0.89 天然气 0.000603 汽油 0.70-0.75 空 气 0.00129 柴油 0.79-0.82 石 膏 2.96 机油 0.90-0.91 玻 璃 2.53 2
三、API套管规范 (下表中除133/8"和20"为短扣外其它均为长圆扣)
通称直径(") 钢级 壁厚(mm) 重量(kg/m) 接箍 外径 (mm) 抗拉强度(t) 紧扣扭矩 (N.m)
抗外挤 Kg/cm2 抗内压 Kg/cm2
41/2 P110 8.56 22.49 127.00 184 5970 737 712 5 N80 9.19 26.78 141.3 179.6 5420 945 980 5 P110 9.19 26.78 141.3 224.1 7200 524 748 5 1/2 N80 9.17 29.76 153.67 194.1 5800 620 646 5 1/2 P110 9.17 29.76 153.67 248.9 7710 778 888 7 N80 9.19 38.73 194.46 235 7040 380 509 7 P110 9.19 38.73 194.46 314 9400 436 669 9 5/8 N80 10.03 59.52 269.88 334.3 9990 217 404 9 5/8 N80 11.05 64.73 269.88 374.2 11190 267 445 9 5/8 N80 11.99 69.94 269.88 410.5 12270 333 483 9 5/8 P110 11.05 64.73 269.88 501.7 15000 311 611 9 5/8 P110 11.99 69.94 269.88 550.2 16450 373 663 133/8 J55 9.65 81.10 365.13 233 6970 79.4 191 20 J55 11.12 139.87 533.39 355 10630 36.3 148
螺纹分类及代号 标准 名 称 使用的符号或代号
API 短圆螺纹 (STC)(CSG或C1) 长圆螺纹 (LTC)(LCSG或C2) 梯形螺纹 (BTC)(BCSG或C33) 直连行螺纹 (XL)(XCSG或C11X) 3
四、环容数据表 （一）各尺寸井眼容积与钻具的环空容积(L/m) 井眼 钻具 311.1mm (76L/m) 241.3mm (46L/m) 215.9mm 36.6L/m 152.4mm (18.24L/m) 备注
8"钻铤 43.65 12 7"钻铤 51.14 22 11.82 61/4"钻铤 56.40 26 17
5"钻杆 63.29 33 23.98 内容积9m3/1000m 43/4"钻铤 6.93
31/2"钻杆 30.39 12.03 内容积3.1m3/1000m
27/8"钻杆 14.05 内容积2.34m3/1000
（二）各尺寸井眼容积与套管的环空容积(L/m) 井眼 套管 311.1mm (76L/m) 241 (46L/m) 215.9mm (36.6L/m) 152.4mm (18.24L/m) 95/8" 28.53 51/2" 20.99 7" 22 11.49
（三）部分常用尺寸和长度的钻杆钢材体积(排代量) 通称尺寸 (英寸) 壁厚 (mm) 平均实际重量(kg/m) 每米排代体积(L/m)
2 7/8" 5.5 9.2 10.91 16.22 1.39 2.07
3 1/2" 6.5 9.3 11.4 15.28 20.53 23.96 1.95 2.63 3.06 5" 9.19 30.65 3.92
备注：127mm钻杆在215.9mm井眼内起出一柱钻杆（按30m长计算），液面下降2.79m；在311mm井眼内起出一柱，液面下降1.34m。 4
五、处理卡钻事故工具 （一）可退式卡瓦打捞筒卡瓦选用表 打捞筒 规 格 卡瓦内径(mm) 落鱼径 (mm) 打捞筒 规 格 卡瓦内径(mm) 落鱼径
(mm) 螺瓦 蓝瓦 螺瓦 蓝瓦
5 5/8
"
(143mm)
111 114 8 5/8" (219mm) 168 171.4 114 117 171 174.5 117 121 174 177.8 83 85.7 121 123.5 86 88.9 124 127 94.5 96.84 150 152.4
7 5/8"" (194mm) 98 100.8 153 155.6 108 111.1 156 158.75 111 114.3 9 5/8"" (244mm) 193 196.58 117.5 120.7 195 198.44 120.5 123.5 197 200.03 123.5 127 168 171.5 148 152.4 174 177.8 151 155.6 10 3/4"" (273mm) 199 203 154.5 158.75 193 196.9
1/8"" (206mm)
154.2 158.75 174 177.8 161 165.1 161 165 164 168.28 155 158.8 170 172 149 152.4 111 114.3 123 127 117.5 120.65 11 3/4"" (298mm) 241 244.5 120.5 123.83 216 219 124 127 225 228.6 150 152.4 5
注：蓝瓦、螺瓦内外螺纹为左旋。捞筒筒体内螺纹为左旋。 （二）可退式打捞矛卡瓦选用表
规格 接头 螺纹 卡瓦 外径 (mm) 被捞落鱼 (mm) 规格 接头 螺纹 卡瓦外径 (mm) 被捞落鱼 (mm)
5 1/2" 41 /2IF 121 118.6 7 5 1/2HF 169 166.10 124 121.4 9 5/8" 7 5/8REG 220.5 216.5 127 124.3 224.5 220.5 128 125.7 226.5 222.4 130 127.3 228.5 224.3
7" 5 1/2HF 154 150.4 230.5 226.6 156 152.5 232.5 228.6 158.5 154.79 13 3/8" 7 5/8REG 315 313.6 160.5 157.07 317.5 315.3 163 159.41 320 317.9 165 161.7 322.5 320.4 167.5 163.98 备注：打捞矛的卡瓦内外扣均为左旋。引锥为正细扣。
（三）开式下击器 型 号 XJ-121 XJ-159 XJ-178 外径尺寸(英寸) 4 3/4 6 1/4 7 抗拉负荷(吨) 122 143 150 密封压力(Mpa) 15 15 15 行程(mm) 1200 1400 1500 水眼直径(mm) 38 51 70 接头螺纹 3 1/2IF 4 1/2IF 5 1/2FH 闭合长度(mm) 2100 2500 2700 6
（四）超级震击器规格 型 号 CS102 CS108 CS121 CS159 CS178 CS203 外径尺寸(英寸) 4 4 1/4 4 3/4 6 1/4 7 8 抗拉负荷 (吨) 100 110 120 140 150 160 密封压力(Mpa) 20 20 20 20 20 20 行程 mm 300 300 305 320 320 320 水眼直径(mm) 38 51 51 57 60 78 总长(mm) 3980 4080 4130 接头螺纹 2 3/8REG 2 7/8IF 31/2IF 41/2IF 51/2FH 65/8REG 备注：目前我油田使用的震击器均为贵州高峰机械厂生产。 （五）随钻震击器规格
型 号 SS121 SX121 SS146 SX146 SS159 SX159 SS197 SX197 外径 (mm) 121 121 146 146 159 159 197 197
最大抗拉(t) 122 122 133 133 143 143 163 163
密封压力(MPa) 20 20 20 20 20 20 20 20
行程 (mm) 305 178 343 178 343 178 368 178
水眼直径(mm) 51 51 57 57 70 70 78 78
打开总长(mm) 5391 4813 5613 5296 5613 5296 5960 5505
接头 扣型 31/2IF 31/2IF 41/2FH 41/2FH 41/2IF 41/2IF 65/8REG 65/8REG 重量330 310 480 457 530 520 980 920
钻井技术员工作手册(2021修订版)
钻井技术员工作手册工程地质技术大队常用取芯PDC钻头规格接头扣型尺寸常用钻杆标准浮力系数表常用钻杆分级标准钻铤分级标准分公司常用钻具结构表层钻具结构：φ445+φ178钻铤×18m+φ195方接头+φ178钻铤×9m+φ195方接头+φ178钻铤×9m+φ159钻铤×52m直井钻具结构：φ203钻头+φ178钻铤×18m+φ195方接头+φ178钻铤×9m+φ195方接头+φ178钻铤×9m+φ159钻铤×72mφ215钻头+φ178钻铤×18m+φ210方接头+φ178钻铤×9m+φ210方接头+φ178钻铤×9m+φ159钻铤×72m∮215 mm〔PDC〕＋∮214 mm螺扶＋∮178 mm钻铤(2m)＋∮214 mm螺扶＋∮178 mm钻铤(9m )＋∮214 mm螺扶＋∮178mm钻铤〔18m〕＋∮214 mm螺扶＋∮178 mm钻铤(9m )＋∮159mm无磁钻铤〔9m〕＋∮159 mm钻铤〔90m〕定向井钻具结构1．直井段：∮220 mm〔PDC〕＋∮178 mm钻铤(18m)＋∮214 mm螺扶＋∮159mm无磁钻铤〔9m 〕＋∮214 mm 螺扶＋∮159 mm 钻铤〔95m 〕 2．造斜段：∮215mm 〔PDC 〕＋∮165 mm 单弯螺杆〔0.75-1.25〕＋直接头＋∮159mm 无磁钻铤〔9m 〕＋∮159mm 钻铤〔54m 〕 3．增斜段：∮215mm 〔PDC 〕＋∮214 mm 螺扶＋∮159mm 无磁钻铤〔9m 〕＋∮159mm 钻铤〔18m 〕＋∮214mm 螺扶＋∮159mm 钻铤〔9m 〕＋∮214mm 螺扶＋∮159mm 钻铤〔95m 〕 4．稳斜段:∮215 mm (PDC) ＋∮214mm 螺扶＋∮159mm 无磁钻铤〔9m 〕＋∮159m 钻铤〔9m 〕＋∮214mm 螺扶＋∮159mm 钻铤〔9m 〕＋∮214mm 螺扶∮159mm 钻铤〔95m 〕∮215 mm (PDC) ＋∮198mm 螺扶＋∮159mm 无磁钻铤〔9m 〕＋∮198mm 螺扶＋∮159mm 钻铤〔9m 〕＋∮198mm 螺扶＋∮159mm 钻铤〔95m 〕钻井液有关计算公式1、 加重剂用量计算公式：w 加=重加原）重原（加r r r r V r --式中：w 加──所需加重剂的重量、吨；r 原 ──加重前泥浆比重 r 重 ──加重后泥浆比重 r 加 ──加重料的比重v 原 ──加重前的泥浆体积、米3；2、 泥浆循环一周所需时间计算公式：T=泵注井Q V V 60-式中：T ──泥浆循环一周的时间、分；V 井──井眼体积 升； V 柱──钻柱体积 升； Q 泵──泥浆泵排量 升/秒；3、泥浆上返速度计算公式：V 返=柱井泵227.12d D Q -=替环容替封t Q Q H 式中：V 返 ──泥浆上返速度 米/秒；Q 泵──泥浆泵排量 升/秒； D 井──井径 厘米； d 柱──钻柱外径 厘米； H 封──封固高度 米； Q 替──替泥浆量 米3； Q 环容──环形容积 米3； t 替──替泥浆量 秒；4、 漏速度的计算公式： V 漏=时漏t Q 式中：V 漏──漏失速度 米3/小时；Q 替──漏失量 米3； t 时──漏失时间 小时； 5、 井底温度计算：T=T0+168H 式中：T ──井底循环温度 0C ； T0──井口循环温度 0C ； H ──井深 米； 6、配置泥浆所需粘土和水量计算： 粘土量W 土=水土水）泥泥（土r r r r V r --水量Q 水=V 泥土土r W 式中：W 土──所需粘土的量 吨；V 泥──所需泥浆量 米3； r 水──水的比重 r 土──土的比重 r 泥──泥浆比重Q 水──所需水量 米3；7、 低比重所需水量计算 Q 水=水稀水稀）原原（r r r r r V --式中：Q 水──所需水量 米3；V 原──原泥浆体积 米3； r 原──原泥浆比重 r 稀──稀释后泥浆比重 r 水──水的比重5″钻杆不同排量时泥浆在不同井眼中上返速度〔米/秒〕加重一立方米泥浆所需重晶石用量表〔公斤〕常用钻井泥浆泵排量与压力容积效率100％，机械效率90％容积效率100％，机械效率90％常用各种钻具容积表方钻杆容积：钻具容积钻具在不同井眼中的环形容积油管体积及内容积表处理卡钻计算公式及数据1、卡点深度 L=KpeK=21F 式中：L ────卡点深度 米e ────平均伸长 厘米 p ────平均拉力 吨K ────计算系数〔见表〕 F ────管体截面积 厘米22、钻杆允许扭转圈数 N=KN式种：N ────允许扭转圈数 圈；K ────扭转系数〔见表〕 圈/米； H ────卡点深度 米； 3、泡油量计算： Q=K41π〔D 2─D 12〕H+41πd 2h 式中：Q ────泡油量 米3 K ────附加系数 一般1.2-1.5 D ────井径D 1────钻杆外径 米 d ────钻杆内径 米 H ────钻杆外油柱高 米 h ────钻杆内油柱高 米 卡点计算系数K 值表物质比重物质比重公锥规范单位：mm注;D G:四川、Q Z：东风厂、其余宝鸡厂母锥规范单位:mm母锥规范单位:mm铅模标准单位:mm磁铁打捞器931/2″—41/2″卡瓦打捞桶标准单位:mm可循环可卸式卡瓦打捞筒可循环可卸式卡瓦打捞筒可循环可卸式卡瓦打捞筒卡瓦选用表铣管选用尺寸表单位:mm铣管选用尺寸表单位:mm吊环标准单位：mm平安卡瓦使用节数喷射钻井水力计算公式A———————喷嘴总面积、厘米2 A V———————环空返速、米/秒Ccb—————钻铤水眼压耗系数Ce—————地面泥浆循环系统压耗系数Cp—————钻杆内外压耗系数Dc—————钻铤外径、毫米Dcb—————钻铤内径、毫米Dh —————井径、毫米Dj —————钻杆接头外径、毫米 Djb —————钻杆接头内径、毫米 Dp —————钻杆外径、毫米 Dpb —————钻杆内径、毫米 Em —————泥浆泵机械传动效率Hb —————钻头水马力 I —————冲击力、公斤IH —————泥浆泵输入功率、马力 Lc —————钻铤柱长度、米 Lp —————钻杆柱长度、米Pb —————钻头喷嘴压降、公斤/厘米2 Ps —————立管压力〔总泵压〕公斤/厘米2 Q —————排量、公斤/秒 V —————喷速、米/秒W —————泥浆比重、克/厘米3 Vm —————环空每米容积、公升/米环空返速 A V=Vm Q 喷速 V=AQ10钻头水马力 Hb=5.7pbQ =233376.13A WQ冲击力 I=1.35255Q pbW =1.0146A WQ 2喷嘴压降 pb=22778.1A WQ公式： 泵输入功率 IH=5.7Em psQ〔传动效率0.85〕钻铤通孔压耗系数 Ccb=Dcb86.41088.77⨯钻铤环空压耗系数 Cca=22271047.17））（（Dc Dh Dc Dh B--⨯ 钻杆内外压耗系数Cp=86.410338.77•⨯Dpb +2227106.16））（（Dp Dh Dp Dh B--⨯ +86.410529.07•⨯Djb +222710873.0））（（Dj Dh Dj Dh B --⨯ 钻杆内外和地面泥浆循环系统压降p=0.001703［Ce+〔Ccb+Cca 〕Lc+LpCp ］WQ 1.86 钻具内外压降p=0.001703LpCpWQ 1.86 钻铤通孔压降p=0.001703LcCcbWQ 1.86 钻铤环空压降p=0.001703LcCcaWQ 1.86地面泥浆循环系统压降p=0.001703CeWQ 1.86 比水马力=）钻头底面积（英寸（马力）钻头水马力2Hb排量系统表全角变化率计算公式K=βCOS a a a a 2122212-+×L∆25 式中：K －全角变化率、度/25米a 1－上测点井斜角、度 a 2－下测点井斜角、度β－上下两测斜点方位之差的绝对值、度 L ∆ －上下两测斜点井深之差的绝对值、米井径扩大率〔％〕=钻头直径钻头直径实测井径-×100％〕泥浆比重=井深地层压力10⨯〔没有附加〕地层压力=立管压力+0.1×比重×井深〔关闭环空〕 替泥浆泵压=101〔H-h 〕〔γ1-γ2〕+0.01L+〔8～16〕 式中：H ——管外水泥柱高度、米h ——管内水泥塞高度、米γ1——水泥浆比重 γ2——泥浆比重 L ——套管下深行程钻速=其下钻时间纯钻进时间钻井进尺（包括取心）+〔米/小时〕钻机月速=钻机台月钻进进尺（包括取心）〔米/台月〕钻机台月=（小时）成止的时间（小时）各口井第一次开钻至完720水泥计算： Q=321V V V + Q ——水泥总代数 V 1——封固段环空 V 2——水泥塞容积V 3——1袋水泥配制的水泥浆容积 替泥浆计算：V 替=V 1+V 2+………V iV i =1000785.02li d 〔m 3〕V i ——不同壁厚的套管内容积 li ——同一壁厚的套管总长注速计算： ①、管内注速：V=60⨯V Qq〔m/S 〕②、管外注速：V 1=601⨯V Qq〔m/S 〕Q —— 每分钟注灰代数 q ——每袋水泥的配浆体积 V ——每米套管内容积 V 1———每米平均环型容积 替速计算： V 替=）替泥浆时间（环形容积）封固高度（替泥浆量S m ⨯⨯〔m/S 〕压井根本数据计算〔一〕关井立管压力：Pd Pd+Pmd=Pp=Pa+Pma式中：Pd ——关井立管压力，公斤/厘米2 Pmd ——钻柱内钻井液压力，公斤/厘米2 Pp ——地层压力，公斤/厘米2 Pa ——关井套管压力，公斤/厘米2Pma ——环空内钻井液柱压力，公斤/厘米2 因此：Pp=pd+0.1γ m ·H式中：γ m ——钻井液比重，克/厘米3 H ——井深，米。
石油钻井操作技术手册
石油钻井操作技术手册一、引言石油钻井是获取地下石油资源的重要工艺，涉及到复杂的操作流程和技术要求。
本手册将详细介绍石油钻井操作技术，包括钻井设备、井眼设计和钻井工艺等方面的内容。
二、钻井设备1. 钻井平台钻井平台是进行钻井作业的基础设施，要求稳固、安全、方便作业。
常见的钻井平台包括陆上平台和海上平台，其细节和特点将在下文中详细介绍。
2. 钻头钻头是进行钻井的重要工具，负责切削地层并将岩屑带出井口。
根据不同的地质条件和井眼要求，选择合适的钻头类型和材质，以提高钻井效率和质量。
3. 钻杆钻杆用于传递转矩和推力，连接钻头和钻机。
其材质和结构要具备足够的强度和刚度，以应对高强度冲击和扭力的要求，保证钻井过程的平稳进行。
4. 钻机钻机是推动钻杆进行旋转和提升的设备，根据不同的钻井作业需求有着多种类型和功率的钻机。
合理选择和操作钻机，能有效提高钻井效率和作业安全性。
三、井眼设计1. 井口结构井口结构一般由井口装置、固井套管和井口防喷设备组成。
井口结构的设计应考虑到井眼要求、固井要求和安全要求，以确保井口的稳定和安全。
2. 钻井液钻井液在钻井过程中起着冷却钻头、悬挂岩屑、平衡井压等重要作用。
根据地质条件和井眼设计要求，选择合适的钻井液类型和性能参数，以保证钻井过程的顺利进行。
3. 套管设计套管是钻井中的重要部件，用于井眼的加固和地层隔离。
根据地质情况和井眼要求，设计合理的套管尺寸、悬挂方式和固井类型，以提高井眼稳定性和完整性。
4. 钻井方案钻井方案是指根据地质和井眼设计要求，确定合理的钻井参数和操作流程，以保证钻井安全和效率。
在编制钻井方案时，要充分考虑地质风险、工程经济和环境影响等因素。
四、钻井操作工艺1. 下井作业下井作业是指将钻杆、钻头等钻井设备送入井口并连接起来的过程。
该过程需要严格控制钻井设备的下降速度和连接质量，以确保下井作业的顺利进行。
2. 钻井作业钻井作业是指进行钻井过程中的旋转、推进和循环等操作。
井下作业实用数据手册
井下作业实用数据手册井下作业实用数据手册前言井下作业是指在井下进行的各种工作任务，它们包括井下施工、维修、保养和检测等。
井下作业是一个复杂而危险的任务，在探矿、煤矿、石油等行业中广泛应用。
井下作业涉及到一系列的操作步骤和安全措施，以确保工人的安全和正常进行作业。
本手册旨在提供井下作业所需的实用数据，包括井下作业的安全规范、操作技巧、设备使用指南等。
第一章井下作业的安全规范1.1 井下作业的危险性和风险评估1.1.1 井下作业的危险因素1.1.2 井下作业的风险评估方法1.1.3 井下作业的安全控制措施1.2 井下作业的安全标准和法规1.2.1 井下作业的安全标准1.2.2 井下作业的法规和规章制度1.2.3 井下作业的示范工作操作指南第二章井下作业的操作技巧2.1 井下作业的操作步骤和要点2.1.1 井下施工的操作步骤和要点2.1.2 井下维修和保养的操作步骤和要点2.1.3 井下检测和测量的操作步骤和要点2.2 井下作业的团队合作和沟通2.2.1 井下作业中的团队协作和分工2.2.2 井下作业中的沟通技巧和工具第三章井下作业的设备使用指南3.1 井下作业的设备选择和准备3.1.1 根据作业任务选择合适的设备3.1.2 设备的准备工作和检查3.2 井下作业的设备使用和维护3.2.1 设备的正确使用方法和注意事项3.2.2 设备的日常维护和保养3.2.3 设备故障的处理和紧急情况的应对第四章井下作业的事故预防和应急措施4.1 井下作业的事故预防措施4.1.1 人员的安全培训和意识教育4.1.2 设备和工具的安全使用和保养4.1.3 作业现场的安全管理和巡检4.2 井下作业的应急措施4.2.1 井下作业的事故应急预案4.2.2 事故发生时的急救和逃生方法结语井下作业虽然危险，但它是工业生产中不可或缺的一环。
只有掌握了相关的安全规范、操作技巧和设备使用指南，才能保障工人的安全和作业的顺利进行。
本手册旨在为井下作业提供实用的数据，为工作者提供参考和指导。
钻井技术员手册
地层压力 10 （没有附加） 井深
1 （H-h） （γ1-γ2）+0.01L+（8～16） 10
地层压力=立管压力+0.1×密度×井深（关闭环空） 替泥浆泵压=
式中：H——管外水泥柱高度,m; h——管内水泥塞高度,m; γ1——水泥浆密度 ,g/cm ; γ2——钻井液密度 , g/cm ; L——套管下深,m. 压井基本数据计算 （一）关井立管压力：Ps P s +P d =P p =P a +P ad 式中： P s ——关井立管压力，MPa; P d ——钻柱内钻井液压力，MPa; P p ——地层压力，MPa; P a ——关井套管压力，MPa; P ad ——环空内钻井液柱压力，MPa. (二)压井所需钻井液的新比重: d 1 d 1 = d +
3
d
µ pv ——塑性粘度，mp a .s; d h ——井眼直径，mm. d c ——钻铤外径，mm. （9）钻头（喷嘴）水功率 P b = P b Q 式中 P b ——钻头（喷嘴）水功率，KW；
P b ——钻井泵实发水功率，KW;
Q ——流量，L/S. (10) 射流喷射速度 VJ= 式中
原 ──原钻井液密度，g/cm 3 ； 稀 ──稀释后钻井液密度，g/cm 3 ； 水 ──水的密度，g/cm 3 .
3、固井常用计算 注水泥量计算： Q=(V1+V2)/V3 Q—注水泥总袋数 V1—封固段环形容积 V2—水泥塞容积 V3—1 袋水泥配制的水泥浆体积 替钻井液量计算： V=V1+V2+……+Vi 2 6 3 Vi=（0.7854di Li）/10 (m ) V—替钻井液量 V1—不同壁厚套管的每米内容积
石油钻井工操作手册
石油钻井工操作手册
石油钻井是一项复杂而精密的工作，需要操作人员具备丰富的经验和专业知识。
本操作手册旨在为石油钻井工提供必要的操作指导，以确保工作安全、高效进行。
1. 钻井前准备
在开始钻井作业之前，必须进行充分的准备工作。
首先，确保钻井设备完好无损，各个部件齐全。
其次，对井口进行检查，清除杂物和障碍物，确保井口通畅。
最后，准备好所有必要的工具和材料，包括扳手、钻头、钻杆等。
2. 钻井操作步骤
a) 将钻头降入井口，确保钻头与井壁垂直接触。
b) 启动钻井设备，逐渐增加转速，开始钻井作业。
c) 监控钻井进度和钻井液循环情况，确保钻井作业正常进行。
d) 定期检查钻头磨损情况，根据需要更换钻头。
e) 在钻到设计深度后，停止钻进，进行井眼清理和固井作业。
3. 安全注意事项
a) 确保操作人员穿戴好安全装备，如安全帽、防护眼镜等。
b) 操作时严格遵守操作规程，严禁违章操作。
c) 遇到突发情况时，立即停止钻井作业，并报告相关部门。
d) 定期检查钻井设备，确保设备正常运行。
4. 紧急处理措施
在钻井作业中，可能出现各种紧急情况，如井喷、设备故障等。
在这种情况下，操作人员应迅速采取相应的措施，包括关闭井口防喷装置、停止钻进、撤离现场等，以确保人身安全和设备完好。
总结：石油钻井工作是一项高风险的工作，需要操作人员具备丰富的经验和专业知识。
本操作手册提供了钻井操作的基本步骤、安全注意事项和紧急处理措施，希望可以为石油钻井工提供必要的指导，确保工作安全、高效进行。
钻井常用数据_表格汇总
终—终了立管压力，MPa ；压—压井所用泥浆密度，g/cm 3；—低泵速时立管压力，MPa。
低立—使用泥浆密度，g/cm3；m、加重剂量：W加=r加* V*（r压-r m）/（r加-r压）—加重剂用量，T；加—加重剂密度，g/cm3；加—加重前原泥浆体积，m3；—压井泥浆密度，g/cm3；压—使用泥浆密度，g/cm3；m=（V总-V钻体）/60Q周—泥浆循环一周时间，min；周—井眼容积，L；总—钻柱体积，L；钻体=12.7Q/（D2-d2）返—泥浆上返速度，m/s；返D—井眼直径，cm；d—钻柱外径，cm。
=D径2/2km—千米井眼容积，m3；km—井径，in。
径=（D2-d2）/12.73环H—卡点深度，m；P—钻杆连续提升时平均拉力，T；L—钻杆连续提升时平均伸长，cm；K—计算系数；K=EF/105=21F。
6公斤/厘米22。
钻杆60（2 3/8″×7.112） 24960（2 3/8″×8） 27473（2 7/8″×9） 38089（3 1/2″×9.35） 491114.3（4 1/2″×10.92） 745127（5″×9.19） 715139.7（5 1/2″×10.54） 898139.7（5 1/2″×9.17） 790139.7（5 1/2″×7.72） 670Ф60×5 180Ф73×5.5 240Ф89×6.5 37514、钻杆允许扭转圈数：N=扭转系数（圈/米）×卡点深度114.3（4 1/2″） D级钢0.00441 E级钢0.00638127（5″） D级钢0.00404 E级钢0.0055139.7（51/2″） D级钢0.00368 E级钢0.0050273（2 7/8″） D级钢0.00957 E级钢0.01340η塑=φ600-φ300 厘泊=5（φ300-η塑） 达因/厘米2表观=1/2φ600 厘泊η=3.3221g φ600/φ300φ600/（500n）达因秒/厘米21、油气上窜速度：V油=（H油-H钻头*t/t迟）/t静V油—油气上窜速度，米/小时；H油—油气层深度，米；H钻头—循环泥浆时钻头所在深度，米；t—从开泵循环到见油气显示的时间，分；t迟—钻头所在井深时的迟到时间，分；t静—泥浆静止时间，小时。
钻井工具手册
总长(mm)
接头螺纹
备注：目前我油田 使用的震击器均为 贵州高峰机械厂生 产。
（五）随钻震击器 规格
型 号 SS121
外径
(mm)
最大密抗封拉压(力t)
(M行P程a)
(mm)
水眼直径(mm)
打开总长(mm)
接头 扣型
水泥浆 密度 1.81 1.82 1.83 1.84 1.85 1.86 1.87 1.88 1.89 1.9
b、按井眼轴线形 状分：两维定向井 、三维定向井。
c、按井斜角分：
低斜度定向井：设 计最大井斜角不超 过15度
中斜度定向井：设 计最大井斜角不超 过15度至45度之 间， 大斜度定向井：设 计最大井斜角在 46度至85度之 间， 水平井：设计最大 井斜角在86度至 120度之间，并沿 水平方向钻进一定 长度的井。根据造 斜井段的曲率半径 又可细分为长、中 、中短、短四种曲 率半径的水平井。
4
1:06
D级 0.007 0.006 0.004 0.0036
扭转系数(圈/米) API E级
中部加厚，mm
接
连接型式
头
外径
内径
管体加接头重量kg/m
管内容积，L/m
管体抗拉强度，KN
接头抗扭强度，KN.m
紧扣扭矩，KN.m
（五）、钻杆接头 扭矩表
公称 尺寸
公称 质量
4
1:06
4
1:04
4
1:04
5
1:04
4
1:06
5
1:04
4
1:06
4
1:06
连续油管钻井手册
连续油管钻井手册1. 简介连续油管钻井是一种用于油田勘探和开发的钻井技术，它通过在钻探过程中持续地将油管下放到井口，使得油井在钻探的同时也进行了壳段的套管，从而提高钻井效率并降低钻井成本。
本手册将介绍连续油管钻井的主要步骤、注意事项以及常见问题的解决方法。
2. 步骤2.1 环境准备在进行连续油管钻井之前，需要做好以下准备工作：•确定油井设计参数，包括钻井深度、钻井液体系等。
•准备好所需的钻具和附件，包括油管、钻头、扩孔器等。
•确保钻井设备、测井设备等工具的正常运行。
2.2 下井前准备在下井之前，需要进行以下步骤：1.将井口清洁干净，确保井口周围没有杂物阻碍油管下放。
2.检查井口设备，确保其完好并准备好连接油管。
3.检查油管，确保其质量合格并进行相应的防腐处理。
4.确定下井方式，可以选择顶快下井或者侧门快捷下井。
2.3 连续油管钻井操作步骤连续油管钻井的操作步骤如下：1.将下一个油管段连接到上一个油管段的末端，并通过专用连接工具进行固定。
2.将已连接好的油管段下放到井口，并加以控制使其安全落到井底。
3.在油管段下放期间，不断监控井口的油压、油温等参数，确保油管下放的稳定。
4.当油管下放到预定深度后，停止油管的下放，并进行必要的固定操作，如撞击（锤击）油管。
5.重复上述操作，直到达到钻井设计要求的深度。
2.4 完井和拆井当油井钻探到设计要求的深度后，需要进行完井和拆井的操作。
1.首先进行套管和封完井工作，即在油管周围灌注水泥，确保井口不会有泄漏。
2.然后拆除油管，使用专用工具逐段拆除油管，并将油管回收。
3. 注意事项在连续油管钻井过程中，需要注意以下事项：•油管下放过程中需要严格控制油压，避免油管的滑脱和扭折。
•油管下放速度不宜过快，以免造成油管卡住或受损。
•在油管下放过程中需随时监控井口参数，如油压、油温等，及时发现异常情况并作出应对措施。
•完井和拆井时，要确保水泥固井质量，防止井内泄漏。
4. 常见问题及解决方法4.1 油管下放失败如果油管下放失败，可能是以下原因导致的：•油管连接不牢固，应仔细检查连接是否正确，并重新连接。
钻井常用数据
钻井常用数据一、最低环空返速:444.5mm井眼:Va=0.41/ρ(m/s) 311.1mm井眼:Va=0.59/ρ(m/s)215.9 mm井眼:Va=0.85/ρ(m/s)式中：ρ密—g/cm3二、最小排量:444.5mm井眼: Qa=142.44*Va 311.1mm井眼: Qa=63.31*Va 215.9 mm井眼: Qa=23.93*Va (L/S)三、喷嘴压降：Pb=0.084*ρ*Q2/de4 (Mpa) de=(d1²+ d1²+d3²)½—cm四、井眼容积:444.5mm井眼: 0.155m3/m 311.1mm井眼: 0.076 m3/m 215.9 mm井眼: 0.037 m3/m五、套管容积:339.7mm: 外0.091 m3/m, 内0.081 m3/m 244.5mm: 外0.047 m3/m, 内0.038 m3/m177.8mm: 外0.025 m3/m, 内0.018 m3/m 139.7mm: 外0.015 m3/m, 内0.011 m3/m六、钻具内容积与排代量: （浮力系数f=1-ρ泥/ρ铁）钻杆5”壁厚:9.19mm内径108mm 重量29.01kg/m 容积0.0092方/m 排代量0.004方/m 0.58方/5柱加重钻杆5”容积0.0046方/m 重量73.5kg/m钻铤9”容积0.0046方/m 排代量0.036方/m 0.94方/柱重量286.0 kg/m8”容积0.004方/m 排代量0.028方/m 0.73方/柱重量219.48 kg/m7”容积0.004方/m 排代量0.021方/m 0.55方/柱重量163.20 kg/m61/4”容积0.003方/m 排代量0.017方/m 0.44方/柱重量123.56 kg/m（螺旋型=常规*0.96）七.泥浆(钻杆)上返速度计算:444.5mm井眼: V=0.007*Q 311.1mm井眼: V=0.016*Q 215.9 mm井眼: V=0.042*Q (m/s)八、油气上窜速度：v上窜=[H油气-（H钻头/t迟）*t显]/t静m/min九、常用换算：1英尺′=12″=0.3048m 1″=8吩 1m=3.28英尺 1吩=3.175mm 1美桶=159L 1英桶=163.654L 额1lbs-ft=1.35m.N 1psi=0.0069Mpa 1000lft=45kN十、F-1600钻井泵（宝鸡）(η=0.925)型号F1600 功率1180KW 冲数120r/min 冲程3048mm缸径180 170 160 150 140 mm压力22.76 25.51 28.84 32.77 34.34 Mpa排量(理论) 46.53 41.51 36.77 32.31 28.15 L/s每冲排量23.26 20.75 18.39 16.16 14.08 L/r（实际选用）21.86 19.51 17.29 15.19 13.24 L/r计算系数1 0.364 0.325 0.288 0.253 0.221 L/r.s计算系数2 0.02186 0.01951 0.01729 0.01519 0.01324 m3/r.min排量Q=冲数×计算系数十一、英、汉对照MW—密度VIS—粘度PV—塑性粘度sec--秒qt—夸脱cps—cm/s YP—屈服点lb—磅Ft—英尺CC--cm³桶—bbl 磅/桶—ppb WL—失水gpm—加仑十二、定向井参数井深Dm或L m 井斜角а(°)方位角Φ(°)垂深D m 狗腿角γ(°)狗腿度к(°) /30m水平长度Lp m 水平位移s m 视平移ν m平移方位角θ(°)装置角ω(°)反扭角& (°)。
石油石化钻井手册 - 钻机钻头钻孔技术说明书
Drilling mechanics and performanceThe drill rate that can be achieved with a specific bit is de-termined by the aggressiveness of its design, the weight on bit (WOB) applied, the rotations per minute (RPM) and the rock strength. When the RPM or WOB are increased, the rate of penetration (ROP) should increase proportionate-ly. If the increase is proportionate, the bit is efficient. Con-sequently, if the ROP does not incease proportionately to WOB, it is because something is making the rock cutting process inefficient. There is a specific dysfunction causing the depth of cut to be less than it should be. When drilling data is examined closely it is clear that in much of the foot-age drilled the bit is not cutting efficiently and this, rather than rock hardness, is the primary cause of low rates of pen-etration. The causes of inefficiency are known and for each type of bit dysfunction there are steps that can be taken im-mediately by the driller to improve the efficiency, ROP, bit life, and borehole quality. There are also engineering rede-sign options, but the focus of this chapter is the actions that can be taken by the driller.Bit mechanicsAll bits drill in a very similar manner. When weight is applied, the cutting structure indents the rock to some depth, and then as the bit is rotated the rock to the right of the buried cutting structure is destroyed. Indentation depth in a given rock is determined by the WOB the driller applies and the ro-tating sliding distance per minute is determined by the RPM used. The volume of rock, or drill rate, is the product of both (Figures DP-1a and -1b ). Indentation depths are not large, and most of the volume of rock removed is from rotation and the distance the cutters slide per minute. For example, the teeth of a more aggressive roller cone bit are aligned to stay on bottom and engaged for a greater distance in the rock, so they remove more rock volume per minute.The expected responses to WOB are shown in Figures DP-2a, -2b and -2c . If the bit is efficient, a plot of ROP vs WOB will form a straight line, regardless of rock strength, bit cut-ters and design, or RPM. The straight line is referred to as a proportionate response, a term that will be used throughout this chapter.Figures DP-2b and -2c show the effects of rock strength and bit aggressiveness. As rock strength increases, more WOB will be required to achieve a given indentation depth (depth of cut). The change in depth of cut and ROP is approximately proportionate to the change in rock strength. For example, ifIndentation depth (WOB)Indentation depth (WOB)Sliding distance per minute (RPM)Figures DP-1a and -1b (from top): All bits essentially work in the same manner. The rock volume removed per minute is determined by indentation depth and the combined distance per minute that the cutters travel while engaged.Higher RPMLower RPMSofter rockHarder rockMoreaggressiveLessaggressiveWOBWOBWOBRate of Penetration (ROP)E ect of RPM and WOBE ect of rock strength and WOBE ect of bit aggressiveness and WOBFigures DP-2a, -2b, and -2c (at right, from top): If the bit is efficient, a plot of ROP vs WOB will form a straight line, regardless of rock strength, bit cutters and design, or RPM. Figure DP-2a: Effectof WOB and RPM. Figure DP-2b: Effect of rock strength.Figure DP-2c: Effect of bit aggressiveness.the rock strength increases by 10% the drill rate should be expected to decline by about 10%.The bit aggressiveness determines the indentation depth and torque that will occur for a given WOB. As shown in Fig-ure DP-2c, a more aggressive bit will drill faster because any given WOB will cause it to indent to a greater depth of cut (DOC) per revolution.When operating efficiently, rock strength and bit aggressive-ness effect the drill rate, but large changes in drill rate are usually due to inefficiency or dysfunction in the rock cutting process. If the bit is efficient, it is only necessary to raise the WOB or RPM in order to drill faster. If the bit is not cutting rock efficiently, the driller must identify and address the cause of dysfunction in order to significantly increase perfor-mance. The types of dysfunctions and the driller’s response will be discussed.If the increase in ROP is not proportionate to changes in WOB or RPM, something is interfering with the indentation depth. The poor response to WOB is referred to as bit founder. For example, Figure DP-3a shows the relationship the driller will observe between WOB and ROP for bit balling, which is one form of founder.As weight is initially applied, bits tend to be inefficient at very low loads. The efficiency increases as the weight is in-creased. In Figure DP-3a the bit has reached its peak effi-ciency at Point 1, and a proportionate response is seen at any WOB between Point 1 and Point 2. When the bit is efficient, increased performance only requires that the driller contin-ue to raise the WOB. Not only will the ROP increase, but it will also increase by the same amount for each incremental increase in WOB. The response is linear, proportionate and predictable. At Point 2, bit balling is beginning to occur, which interferes with the depth of cut. The bit becomes even less efficient if additional WOB is applied. Point 2 is referred to as the founder, or flounder point. The driller achieves peak per-formance by determining the WOB at which the bit founders and operating with a bit weight that is close to that point. The process of determining the founder WOB is repeated for var-ious rotary speeds.In the case of bit balling, it is also useful for the driller to con-duct step tests with the third parameter that he controls, which is flow rate. Whether flow rate has any effect on per-formance depends on the cause of bit dysfunction, but in-creased flow rate is almost always effective in increasing the founder point for bit balling.Once the driller goes through the process of identifying the founder point, parameters are used that keep the operation at or just below founder. Performance has been maximized and cannot be improved further unless the cause of ineffi-ciency is addressed and the founder point is increased to a higher WOB.Figure DP-3b shows what should occur to increase perfor-mance further. In the case of bit balling, for example, if pump horsepower is not already fully utilized, the driller can change the founder point by increasing the flow rate and nozzle fluid velocity. This keeps the bit clean to a higher depth of cut and drill rate. Founder will still occur, but at a higher WOB. In one field case, the founder point and achievable ROP were elevat-ed from 120 ft/hr to 500 ft/hr with the same bit when the bit hydraulics were improved.It might not be necessary for the driller to know why the bit is foundering to find the best current operating parame-ters. However, it is necessary to know the cause of founder in order to take the specific action required to significantlyROPWOB WOBFigures DP-3a, -3b (from left): shows a straight-line response of ROP to WOB, indicating an efficient bit up to the founder point. The driller must limit WOB to remain at or below the founder point. Figure DP-3b shows the result of changing real-time practices or design that elevate the founder point to a higher WOB. The WOB the driller can now apply without foundering is increased, as is the achievable ROP.improve the current limitations. For example, increasing the nozzle velocity will not improve performance if drillstring vibrations are causing bit inefficiency. Therefore, the driller must have the knowledge and ability to determine the root cause. The drill team’s ability to identify the root causes of rock-cutting dysfunction in real time has been greatly en-hanced by the digital data now collected and the manner in which it is processed and displayed on many rigs. There are specific actions the driller can take to improve bit efficien-cy for every cause of dysfunction, and many other design changes that can be made by engineering.Testing bit performanceMost performance tests take the form of some type of step test. An example step test for determining inefficiency is shown in Figure DP-4a . In this case, the driller increases the WOB by 5,000 lb and the drill rate increases by 25 ft/hr. If the bit is efficient, the next 5,000 lb should yield another 25 ft/hr increase. If the drill rate increases by less than 25 ft/hr after the next step in WOB, the response is not propor-tionate. The increased weight has caused some form of rock cutting dysfunction (founder). While the drill rate has still increased, the bit has become less efficient. ROP will usually increase with WOB, but if the increase is not proportionate, something is wrong. The drilling performance is less than it should be, and the dysfunction might also be damaging to the bit. The same step test process can be applied when changing RPM. Increase RPM in fixed steps (i.e., 5 rpm), and ROP should increase proportionately and by the same amount with each step.As long as a proportionate response is seen from step to step, increased performance only requires that the driller continue to increase WOB or RPM to drill faster, and also to avoid damaging the bit or BHA. It is important that each stepin WOB or RPM be exactly the same. If the bit is efficient, a proportionate response will yield exactly the same increase in ROP, which is easy to see. If the steps are not exactly the same, the data can still be used, but the driller must physical-ly plot the ROP to see if the response plots as a straight line, as shown in Figure DP-4b . Using identical steps eliminates the need for plotting; it is only necessary to see that the ROP change is the same with each fixed step in WOB to know that the response is proportionate (straight line).If a downhole motor is being used, the same WOB step tests are conducted, but the motor differential pressure may also be used to observe a proportionate response, rather than just ROP. If the differential rises proportionately with each in-crease in WOB, the bit is efficient. If the pressure response is less than proportionate, the rock-cutting process is becom-ing inefficient.Drill-off testing is a method developed in the 1950s to min-imize the time to determine performance at various WOBs (Figure DP-5). The process works well with roller cone bits at moderate to low drill rates, but it tends to be less effec-tive with PDC bits. The driller applies a high WOB, locks the top-drive position, and continues rotation. The rotating bit drills ahead and the locked string elongates, transferring the drillstring weight that had been applied to the bit back to the hook. The amount of drillstring elongation is called “stretch”. The rate at which the hookload increases then provides an indication of how fast the string is elongating, which is also the bit drill rate .In the following example, the driller is recording the time re-quired for each additional 3,000-lb increase in hookload to occur, which corresponds to a 3,000-lb decrease in bit load. The ROP can be calculated and plotted during each incre-D e p t hWOB (K lbs)WOB (K lbs)ROP (ft/hr)R O P (f t /h r )510152025905101520253085755025Founder pointFigures DP-4a and -4b (from left): In Figure DP-4a, : WOB is increased in 5,000-lb steps, and ROP responds by increasing 25 ft/hr with each step, up to 20,000 lb. Between 15,000-20,000 lb the bit founders, and the next increase in ROP is less than 25 ft/hr (10 ft/hr). If the driller were to plot the average ROP at each WOB from the test in Figure DP-4a, it would produce the curve shown in Figure DP-4b. Founder isthe point at which the data is no longer a straight line (non-linear response).ment by the string stretch equation shown below. Stretchconstants for API DP may be found in reference manuals.DP Stretch= (Stretch Constant for specific DP)*(DP Length)*(Step Change in WOB) Eq 1Where units are:DP Stretch, in.;Stretch Constant, (in./k lb)/k-ft;DP Length, k ft; Step Change, k lb“k” indicates thousandsROP = (DP Stretch/Time)*[(3,600 sec/hr)/12 in./ft)Where units are:ROP, ft/hr;DP Stretch, in.;Time, secThe advantage of plotting data is to document the results andallow it to be communicated offsite. If documentation is notneeded, drillers usually conduct the test by simply observingthe time required for each increment of weight to drill off andthen using the WOB corresponding to the fastest time. In thisexample, the fastest drill rate would be seen at a WOB cor-responding to the 11- or 12-sec drill-offs (positions number 2and 3 in Figure DP-5).Mechanical Specific Energy (MSE) surveillance is anothermethod for determining drilling performance. Drill-off testsare well suited to roller-cone bits, intermediate drill stringlengths with significant stored stretch, and bit balling. But theprocedure does not produce clear results with PDC bits thatdrill with very light WOB, because the weight may drill offbefore meaningful data can be collected. Also, complex vi-brations tend to dominate bit dysfunction with PDC bits. Forthese reasons, surveillance practices have been developed inrecent years to continuously plot the amount of work the bitis doing, and this value shows whether the bit is becomingmore or less efficient as changes are made in parameters.Mechanical Specific Energy is the work or energy being usedper volume of rock drilled. MSE is plotted by the data-acqui-sition computer alongside other drilling data, such as WOB,RPM and ROP. In theory, if the bit is perfectly efficient, thevalue of the MSE equals the rock strength in psi. But in fieldpractice, it is primarily used as a relative indicator and it isnot necessary to know the rock strength. The driller makes achange and observes the MSE to see if rock cutting efficiencyimproved or declines.Figure DP-6 shows an MSE curve from a well in which bitballing is occurring. The footage where the MSE is high in-dicates that there is dysfunction (in this case, bit balling).When the bit drilled from a shale back into a sand, the MSEfell, indicating the bit’s cutting structure has cleaned up andis now operating efficiently. Changes in rock hardness alsoaffect the energy required, but this is minor when comparedto the energy increase when bit dysfunction occurs, so theselarge changes in MSE are very useful in showing dysfunction.When combined with other information, it can also be usedto determine the cause of the problem.Chasgnes in MSE can be related to effects of dysfunctionshown in Figure DP-7. If the MSE increases when a changeis made, the performance is moving further way from the ef-ficient performance, which would be the dashed blue line. Ifit decreases, the performance is moving closer to the dashedline. For example, the curve for whirl shows that if WOB is in-creased, the ROP performance moves closer to the predictedline, which means that inefficiency due to whirl is decreasing,and we would expect the MSE to go down. This is used as aCalculated weight on bitCalculated R OP(3) 12 sec, 109 k #(4) 15 sec, 112 k #(5) 17 sec, 109 k #Figure DP-5: Drill-off test conducted by observing the time required to drill off 3,000-lb increments of weight on bit. The highest ROP occursat the WOB corresponding to the shortest required time per increment.diagnostic. If the WOB is increased, and the MSE declines, we know that whirl was the cause of dysfunction to start with. As shown in Figure DP-7, there is no other dysfunction that improves as WOB is increased (e.g., moves closer to the dashed line). In order to identify some of the other forms of founder, it is necessary to observe additional data, or to have more information about the drilling conditions. This is dis-cussed in the sections below.Regardless of the cause of dysfunction, the manner in which the driller uses the MSE to maximize real time performance is the same. To get this performance, the driller must conduct step tests by changing one parameter at a time (WOB, RPM or GPM).If the MSE declines the dysfunction is getting better and performance is improving. Continue with more of thesame change (i.e., even higher WOB);If the MSE increases, the dysfunction is becoming worse and performance is declining. Change theparameter in the other direction (i.e., reduce the WOB); If the MSE stays the same performance is on the straight line portion of the drill off curve in FigureDP-3a. Continue increasing WOB to founder.It should be emphasized that the driller cannot simply ob-serve the MSE curve and diagnose most root causes, or de-termine the next action. Step tests must be conducted, and the MSE response to the change observed. It is the response that is diagnostic.Causes of drilling dysfunctionsEach of the categories of bit dysfunction will be discussed, as well as the observations that can be made to diagnose what is occurring in real time. The corrective actions that can be taken immediately at the rig site will also be dis-cussed. Figure DP-7 shows the effect that each of the major forms of dysfunction may have on ROP as WOB is increased. At any given point in time only one of these usually domi-nates. However, this is not always true and that can com-plicate diagnosis. The types of rock cutting dysfunction dis-cussed are:Bit balling: buildup of material on the bit that interferes with depth of cut;Interfacial severity: formations with hard inclusions or layers that cause axial shocks and break cutters;Bottomhole balling: layer of ground cuttings held to the bottom of the hole by differential pressure;Whirl vibrations: lateral motion of the string and bit;Stick-slip vibrations: torsional motion in which the bit speed oscillates periodically;Axial vibrations: axial motion in which the bit depth of cut oscillates periodically.The flow chart in Figure DP-8 summarizes a progression of activities to maximize performance. There are five forms of dysfunction shown and the driller’s response to each. There are also numerous engineering redesign options, but these are not within the scope of the chapter. The flow chart is not self-explanatory and the dysfunctions, testing procedures and responses are contained in the detailed discussions to follow.Bit ballingBit balling occurs when drilled material accumulates on the cutting structure that begins to carry some of the applied WOB, so that the weight on the cutter tips is reduced. Con-Causes and e ects of founderE cient bitw/expected DOCRate of penetration (ROP)Bit ballingWhirlStick-slipInterfacial severityBottomhole ballingWOBFigure DP-6: Example Mechanical Specific Energy (MSE) plot showing severe bit dysfunction in shales due to bit balling and efficient drilling in sands. Nozzles were changed during a trip to increase bit cleaning and the MSE curve now shows both shales andsands drilling efficiently.Figure DP-7: Founder, or rock-cutting dysfunction, causes the depth of cut and ROP to be less than it should be for a given WOB, causing performance to decline. The order in which the various dysfunctions are seen as WOB is increased will vary and must be determined bythe driller in an organized step test.。