WellPlan Exercie Book

WELLPLANExercise Book

2003.5.0.2 (EDM 2003.5.0.2 (03.13.03))

copyright © 2003 by Landmark Graphics Corporation

Part No. 161753, Rev. A, V2003.5.0.2 September 2003

HBL4192

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NoteThe information contained in this document is subject to change without notice and should not be construed as a

commitment by Landmark Graphics Corporation. Landmark Graphics Corporation assumes no responsibility for any error that may appear in this manual. Some states or jurisdictions do not allow disclaimer of expressed or implied

warranties in certain transactions; therefore, this statement may not apply to you.

Contacting SupportLandmark operates a number of Technical Assistance Centers (TACs). Additional support is provided through district support offices around the world. If problems cannot be resolved at the district level, Landmark’s escalation team is called to resolve your incidents quickly.

Support information is always available on the Landmark Graphics Support internet page.

Technical Assistance Centers

North America (Houston, Texas)713-839-2200 or toll-free 1-877-HELP-LGC

7:30 am - 5:30 pm CST/CDTMonday - Friday, excluding holidaysFax: 713-839-2168Email: [email protected]

South America (Houston, Texas)713-839-3405

7 am - 5:00 pm Local TimeMonday - Friday, excluding holidaysFax: 713-839-3646Email: [email protected]

United Kingdom (Leatherhead) 44-1372-868686

8 am - 5:30 pm Local TimeMonday - Friday, excluding holidaysFax: 44-1372 868601 Email: [email protected]

Europe and Africa44-1224-778500

24 hour support including weekends and holidays

**NOTE: 24 hour support is for DIMS only. WellPlan, Compass, and Profile are supported business hours: 8 a.m. - 6 p.m. Local Time, Monday - Friday, excluding holidays.

Telephone: +44-1224-778500

Email: [email protected]

Middle East and North Africa9712-676-1745

Fax: 9712-672-5924Support Mobile Phone: 971-50-551-7273Email: [email protected]

Asia Pacific International61-8-9481-4488 ortoll-free 1-800-448-488

8:30 am - 5:30 pm Local TimeMonday-Friday, excluding holidaysToll-Free Numbers:10-800-6100-253 (China)001-803-61284 (Indonesia)00531-61-0021 (Japan)1800-803-687 (Malaysia)0800-400-555 (New Zealand)1800-1611-0207 (Philippines)00308-61-0046 (South Korea)0080-61-1350 (Taiwan)001-800-611-2784 (Thailand)Email: [email protected]

Bangladesh, Brunei, India, Pakistan, Vietnam61-8-9481-4488


District Support Offices

Argentina (Buenos Aires)54-11-4812-5888 or toll free 1-800-800-5263

8:30 am - 5:30 pm Local TimeMonday-Friday, excluding holidays Fax: 54-11-4812-9777Email: [email protected]

Australia1800-448-488


Australia (Melbourne)61-3-9820-2486

8:30 am - 5:30 pm Local TimeMonday - Friday, excluding holidaysFax: 61-3-9828-5365Email: [email protected]

Australia (Perth)61-8-9481-4488 or toll free 1800-448-488


Brazil (Rio de Janeiro)55-21-3974-4000 or toll free 000-814-550-3785

8 am - 5 pm Local TimeMonday - Friday, excluding holidaysEmail: [email protected]

Chile (LAO TAC, Houston, Texas)800-201-898

7 am - 5 pm CST/CDTMonday - Friday, excluding holidaysFax: 1-713-839-3405Email: [email protected]

China10-800-6100-253


Colombia (Bogota)571-326-4000 and 571-326-6710 or toll free 1-800-915-4743

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Indonesia001-803-61284


Indonesia (Jakarta)62-21-526-5555 or toll-free 001-803-61284


Malaysia1800-803-687


Malaysia (Kuala Lumpur)60-3-2164-1121 or toll free 1800-803-687

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Mexico (LAO TAC, Houston, Texas)52-52083533 and 52-52083868 or toll free 011-888-438-1296

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Trinidad (LAO TAC, Houston, Texas)1-888-438-1296

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United Arab Emirates (Abu Dhabi)9712 676 1745

Fax. 9712 672 5924Email: [email protected] Mobile is 97150 551 72 738:30am - 5pm Local Time, Saturday-Wednesday, excluding holidaysOut of office hours support provided for DIMS only, call Support mobile number.

United Arab Emirates (Dubai) +971-4-331-3142(ask for Landmark Technical Support)

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United Kingdom (Aberdeen)44 (0)1224 778500

8:30am - 5pm Local Time, Monday-Friday, excluding holidaysFax. 44 (0)1224 778555Email: [email protected] of office hours support provided for DIMS only, call above number and request Oncall Support.

Helpful internet links are shown below.

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Vietnam (Ho Chi Minh City)84-8-910-1901

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Name Website Address

Landmark Graphics home page http://www.lgc.com

Landmark Graphics FTP Site ftp://ftp.lgc.com

Oracle home page http://www.oracle.com

FLEXlm license management software home page

http://www.globetrotter.com/flexlm.htm

Microsoft SQL Server home page http://www.microsoft.com/sql/default.asp

Adobe Acrobat Reader http://www.adobe.com

Microsoft MSDE http://www.microsoft.com/sql/default.asp

Landmark WELLPLAN Exercise Book

September 2003 Contents ix

Contents

Contacting Support ............................................................................................................. 3WELLPLAN Exercise Overview ....................................................................................... 11Exercise 1: Creating the Data Hierarchy ............................................................................ 14Exercise 2: Specifying Tubular Properties, and Working With Catalogs .......................... 16Exercise 3: Using the Case Menu ....................................................................................... 18Exercise 4: Using Torque Drag Analysis ........................................................................... 23

Steps and Questions ..................................................................................................... 23Answers ....................................................................................................................... 25

Exercise 5: Using Hydraulics Analysis .............................................................................. 33Steps and Questions ..................................................................................................... 33Answers ....................................................................................................................... 36

Exercise 6: Using Well Control Analysis ........................................................................... 50Steps and Questions ..................................................................................................... 50Answers ....................................................................................................................... 54

Exercise 7: Using Surge Analysis....................................................................................... 67Note .............................................................................................................................. 67Steps and Questions ..................................................................................................... 67Answers ....................................................................................................................... 69

Exercise 8: Using Cementing - OptiCem ........................................................................... 84Steps and Questions ..................................................................................................... 84Answers ....................................................................................................................... 86

Exercise 9: Using Critical Speed Analysis ......................................................................... 99Steps and Questions ..................................................................................................... 99Answers ....................................................................................................................... 100

Exercise 10: Using Bottom Hole Assembly Analysis ........................................................ 107Steps and Questions ..................................................................................................... 107Answers ....................................................................................................................... 107

Exercise 11: Using Stuck Pipe Analysis............................................................................. 110Steps and Questions ..................................................................................................... 110Answers ....................................................................................................................... 111

Exercise 12: Using Notebook ............................................................................................. 114Steps and Questions ..................................................................................................... 114

WELLPLAN Exercise Book Landmark

x Contents September 2003

Landmark WELLPLAN 11

WELLPLAN Exercises

WELLPLAN Exercise Overview

The exercises in this book are designed to familiarize you with WELLPLAN. All of the exercises analyze a single well, however not all exercises analyze the same hole section. You will analyze running and cementing an 11 3/4” liner. You will also analyze drilling the 14 3/4” hole section which is drilled after setting the liner. This well has a weak zone that complicates much of the design.

Exercise 1: Creating the Data HierarchyIn this exercise you will create a new company, project, site, well, wellbore, design, and case.

Exercise 2: Specifying Tubular Properties and Working With CatalogsIn this exercise, you will create a new pipe grade and then use this pipe grade to create a new pipe in an inventory you create. You will also review creating a unit system and importing a catalog.

Exercise 3: Using the Case MenuThis exercise builds on the previous two exercises. Using the data hierarchy created in Exercise 1, you will specify additional data that defines the case you are analyzing. You will use the information you entered into the catalog in Exercise 2 as well as use the catalog you imported.

At the end of this exercise, you will import an xml transfer file that contains data you will be analyzing during the rest of the course. The data you import is very similar to what you specified in the previous exercises. In order to ensure that all course participants have the same data for the rest of the exercises, an xml file is imported.

Exercise 4: Using Torque Drag AnalysisDuring this exercise, you will become familiar with using the Torque Drag module. You will analyze drilling the 14.75” hole section. You will use Drag Charts to quickly look for trouble areas. You will follow this analysis with the Normal Analysis for a more in depth investigation of certain areas.

1

WELLPLAN Exercises

12 WELLPLAN Landmark

Exercise 5: Using Hydraulics AnalysisDuring this exercise, you will use the Hydraulics module to determine the minimum flowrate to clean the 14.75” hole section. You will also determine the maximum flowrate to avoid turbulent flow, and optimize bit hydraulics. You will also determine the tripping schedule, and predict ECD while tripping.

Exercise 6: Using Well Control AnalysisIn this exercise, you continue to analyze the 14.75” hole section. You predict the type of kick to expect given certain circumstances. You estimate the volume of the influx and the pressure to expect given the size of the influx. The kick tolerance is investigated and a kill sheet is prepared.

Exercise 7: Using Surge AnalysisThis exercise examines the surge and swab pressures to expect while running the 11 3/4” liner. The exercise also examines tripping and reciprocating the 12 1/4” BHA in the 14 3/4” hole section.

Exercise 8: Using Cementing - OptiCem

This exercise analyzes cementing the 11 3/4” liner. Circulating and wellhead pressure are investigated, in particularly near the fracture zone.

Exercise 9: Using Critical Speed AnalysisThis exercise examines a range of rotating speeds while drilling the 14 3/4” hole section to determine which speeds may result in damaging vibrations.

Exercise 10: Using Bottom Hole Assembly Analysis

This exercise predicts the behavior of the 12 1/4” BHA while drilling the 14 3/4” hole section.

Exercise 11: Using Stuck Pipe Analysis

Using the Stuck Pipe Analysis module, you will determine the loads required to set, trip, and reset the jar. You will determine the load required to backoff at a specified measured depth, as well as the load that will fail the string.


WELLPLAN Exercises

Exercise 12: Using Notebook

You will review the analysis options available within the Notebook module.

WELLPLAN Exercises


Exercise 1: Creating the Data Hierarchy

1. Launch WELLPLAN (Start > Programs > Landmark EDM > WELLPLAN).

2. Enter EDM as the User ID and landmark as the Password on the login screen.

3. Create a new company. Using the Well Explorer, right-click on “EDM 2003.5db” and select New Company from the menu.

4. Specify Company properties.

a) Using the Company Properties > General tab, rename the company Class.

5. Create a new project when prompted or by using File > New > Project.

a) Use the Project Properties > General tab to specify project properties. Name the project Kananga. Use Mean Seal Level as the System Datum.

6. Create a new site when prompted by clicking the Yes button.

a) Use the Site Properties > General tab to specify general site information. Name the site Largo North Platform. The Default Site Elevation is 114.8 feet above MSL. Use Grid as the North Reference. Do not apply a tight group. (Use Unrestricted.)

7. Create a new well when prompted by clicking the Yes button.

a) Use the Well Properties > General tab to specify general well information. Name the well LPN-004. Use API units and no Tight Group. Leave other tab fields blank.

b) Use the Well Properties > Depth Reference tab to specify the well depth reference, configuration (offshore or onshore), and to view a depiction of the datum. Create a datum titled DFE with a 114.8 ft elevation. This datum is the default datum. (Check the Default box.) The rig name is Scorpion 100. This is an offshore well in 328.1 ft of water. Specify an 84.8 ft wellhead elevation.

8. Create a new wellbore when prompted.

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Hierarchy 【‘haiera：ki】 1. 等级 2. 体系 3. 谱系 4. 分层 5. 系统 6. 层次 7. 级别 n. 1. 僧侣统治集团，僧侣统治 2. 统治集团 The government is a hierarchy. 政府是个官阶分明的统治集团。 3. 等级制度，特权阶级 a sense of hierarchy 等级观念 put honesty first in her hierarchy of values 把诚实放在她自己的价值等次的首要地位 a hierarchy of moral values 道德价值的层次 4. [宗]天使团，天使的级别 5. 动、植物学的分类（纲，目，科，属等） 6. [计]数据层次 hierarchy of memory; 分级存储器系统 7. 体系[制]，系统，谱系

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【lc:nch】入水 2. 下水 3. 滑曳 4. 起飞 5. 发射 6. 施放 7. 着手 8. 开办 9. 创办 10. 提出 11. 发起 12. 展开 13. 激励 14. 小汽船 15. 大舢板 16. 开始 17. 投入 vt. 1. 使（船）下水 launch a ship 2. 使船下水 3. 发射（导弹等）；使（飞机）升空 launch an artificial satellite 4. 发射人造卫星 launch a rocket 5. 发射一枚火箭 launch a torpedo 6. 发射一颗鱼雷 7. （把孩子等）送出，使独立谋生 launch one's son into the world 8. 把儿子送到社会上 9. 开办，创办 launch a new enterprise 10. 创办一个新企业 launch a career 11. 开创一项事业 launch a business venture 12. 开始一项冒险事业 13. 发动，开展 launch an attack 14. 开始攻击 launch a mass production movement 15. 开展群众性生产运动 16. 投，掷 launch a spear 17. 掷标枪 18. 推出（新产品）介绍给大众或市场 Launched the new perfume with prime-time commercials on the major networks. 19. 依靠在主要的电视台播出黄金时段的广告来推出这种新型香水。 vi. 1. 起飞，下水 A bird launched off. 2. 小鸟飞走了。 3. 投入，参加 4. 开始，着手前进 5. 从事 launch forth on a dangerous mission 6. 开始执行一项危险的使命 launched out on her own after college 7. 她大学毕业后展开新生活 8. 投入充满热情地进入；投入 launched into a description of the movie 9. 陷入电影情节当中 n. 1. 发射；（船）下水式 launch airplane 2. 火箭运载机 launch pad 3. （火箭等的）发射台 launch window 4. 发射时限 5. 汽艇，游艇，小艇[船] [短语] 1. air launch [航] 空中发射 2. clear launch 正确发射 3. launch out 出航，乘船去；开始；着手；大肆挥霍 4. launch (out) into 开始从事，投身于开始从事，投身于；大发（议论），出（恶言） 5. orbital launch 轨道发射 6. winch launch; （滑翔机）绞盘车牵引起飞

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鼠标右键单击

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1. 指定；详述；载明 The regulations specify that you may use a dictionary in the examination. 2. 规则规定考试时可使用字典。 specified the amount needed. 3. 明确说明所需的数量 4. 详列，逐一登记，列入清单 specified that they be included in the will 5. 他们被列入遗嘱中作为条件 n. 区分符，分类符，指定成分 [短语] 1. as specified 按照说明 2. not specified 未说明技术条件的；未标明的 3. unless otherwise specified 除非另有规定 4. specify by 用……说明[表示]

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1. 性质 2. 特性 3. 财产 4. 矿地 5. 找矿租地 6. 所有权 7. 性能 8. 所有物 9. 属性 10. 资产 11. 物性 n. 1. 财产；所有权 This car is my property. 这车是我的财产。 common property 公共财产 Is this your property? 这是你的东西吗？ The secret is common property. 那个秘密人人都知道。 2. 房产；地产；房地产 He has a small property. 他有一小块房地产。 3. 性质；特征；属性 Many plants have medicinal properties. 许多植物具有药性。 the metal properties 金属性能 4. 道具 stage properties 舞台道具 [短语] 1. abandoned property 废弃财产，已放弃产权财产 2. acidic property 酸性 3. additivity property 相加性，加成性，加和性 4. adhesive property 胶粘性，粘结性，粘着性 5. adhesive property of oil 润滑油（在金属表面形成）粘着（薄膜的）性能 6. agglutinating property 烧结性 7. agrarian property 土地所有制；地产 8. algebraic property 代数性质 9. alien property 外国财产 10. all-round property 全面性能；综合性能 11. alternating property 交替性质 12. amphipathic property 亲两性；亲水亲油性 13. anticatalytic property 反催化性 14. property animal 惯于演出的动物 15. property in copyright 版权所有 16. property owner 地主，业主 17. property tax 财产税

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1. 把…列表 2. 标志 3. 跳格键 4. 制表键 5. 选出

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1. 敏捷的 2. 迅速的 3. 瞬变的 4. 促使 5. 推动 6. 瞬时的 7. 提示 8. 立刻的 adj. 1. 敏捷的，迅速的；即刻的，（回答等）及时的 be prompt to obey commands 立即服从命令 a prompt reply 迅速答复 prompt goods 须当场付款的商品 a repairshop known for its prompt service 一家以服务迅速出名的修理店 2. [商]即期付款的；当场交付的 3. （演剧中的）提词员的 n. 1. 提示；（给演员的）提示，提词 The play was so regularly performed that there was no need of written prompts. 这戏经常演出，没必要使用书面提示。 take a prompt （演员）按提示而行动或念台词 prompt side 提词员所在的一侧；[英]舞台上演员的左方；[美]演员的右方 prompt box 2. [剧]提词人藏身处 3. [商]（期货的）付款日期，交款日期 prompt note; 期货金额及交割日期通知单 prompt sale 期货交易 What is the prompt? 付款期是哪天？ 4. 催款单；催促，提醒 vt. 1. 刺激，鼓励，怂勇，煸动，唆使，挑拨 What prompted you to do such a thing? 什么促使你做出这种事？ A noise prompted the guard to go back and investigate. 嘈杂声促使卫兵回头调查。 The man confessed that poverty prompted him to steal. 这个男子承认是贫穷促使他偷窃的。 2. 激起，唤起（思想感情等） He was prompted by patriotism. 他为爱国心所驱使。 The accident prompted a review of school safety policy. 这场事故引起对学校安全制度的反思。 3. 提醒，指点，给（演员）提词 adv. 准时地，正好 at seven prompt 在七点正 [短语] 1. prompt book 提词用的剧本 2. prompt day [商] 交割日 3. prompt delivery; 即交，即送 4. prompt in 对……很迅速 5. prompt note; 期货金额及交割日期通知单 6. prompt sale; 即时出售 7. prompt side [英]舞台左侧（提词人所站的一边） [复合词] promptbook n. 提词用的剧本 [派生词] prompter n. 敦促者 promptive adj. 推动的，敦促的，激励的，激起的 promptly adv. 敏捷地，迅速地 promptness n. 敏捷，机敏

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1. 不受限制的 2. 非约束的 3. 自由的 4. 无约束的 5. 无限制的 adj. 不受限制的；不受约束的；自由的 [短语] 1. unrestricted automation 非限制自动机 2. unrestricted flow 无限制流动；自由流动 3. unrestricted grammar 不加限制文法 4. unrestricted grant （不论学习单位和科目而给予学生的）非限制性经济补助 5. unrestricted invariant 无约束不变式 6. unrestricted random sample 非约束随机样本 7. unrestricted scholarship 不受条件限制的学生奖学金 8. unrestricted space 无限制区 9. unrestricted variable 无约束变量 10. unrestricted wrestling 自由式摔跤

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1. 不规则地震反射结构 2. 复合S形斜交反射结构 3. S型斜交型混合反射结构 4. 结构 5. 构型 6. 配置 7. 图形 8. 地形 9. 外形 10. 轮廓 11. 组合 12. 分布 13. 表面配置 14. 排列 15. 组态 16. 位形 17. 排列形式 18. 表面装置 19. 浮动装置 20. 构形 21. 几何形态 22. 排布 23. 组合形式 24. 亚平行地震反射结构 n. 1. 外貌；轮廓；形状；结构；构造；图[外]形 2. [计] 配置 3. 组合，布置 4. [天] （行星等的）相对位置，方位 5. [化] （分子中原子的）构型，排列 6. [物] 位形；组态 7. 线路接法 [短语] 1. algebraic configuration 代数构形 2. bouquet configuration 花束象 3. configuration control register 配置控制寄存器 4. configuration counting series 构形计数级数 5. configuration files [计]配置文件 6. configuration frame 构成帧 7. configuration interaction [物化]构型作用；组态相互作用 8. configuration management [管理]结构管理 9. configuration of earth 地形 10. configuration of equilibrium 平衡组态 11. configuration of sample 样本的构形（统计数学用词） 12. configuration section 结构节 13. configuration space 构形[构位]空间 14. configuration theory 完形说 15. configurational entropy 位形熵 16. configurational family 构型族 17. configurational free energy 构形自由能 18. configurational partition function 构形配分函数 19. configurational statistics 构形统计学 20. configurational stimulus 构形的刺激 21. canard configuration 鸭式构型，鸭型 22. cascade configuration 叶栅外形[组合] 23. casing configuration 壳体的几何形状 24. cell configuration 单元形状 25. chain configuration 链构型 26. chamber configuration 燃烧室外形 27. chaotic seismic reflection configuration 不规则地震反射结构 28. cis-trans configurations 顺反构型

user20

[di'pikshn] 1. 描写 2. 描述 3. 描绘


WELLPLAN Exercises

a) Use the Wellbore Properties > General tab to define general information about the wellbore. Name the wellbore ST1.

9. Create a design for wellbore ST1. Name the design P1. Use DFE @ 114.8 ft (Scorpion 100) as the depth reference. This well is a sidetrack from wellbore 1. WELLPLAN isn’t concerned with tie-on information. Case > Wellpath Editor defines the wellpath that will be used for analysis. Other Landmark Drilling Software use sidetrack data. Because the data used in WELLPLAN training is also used for training of other software products that are concerned with tie-on information, this well is labeled ST1.

10. Create a case for design P1. Name the case 14 3/4” Hole Section.

user20

adj. 1. 挂……念的，担……心的 I am very concerned about her. 我非常挂念她。 2. [常用于名词之后]有关（方面）的，被牵连的；忧虑的 the authorities concerned 有关当局 the parties concerned 关系人，当事人（the） quarters concerned 有关方面 Where work is concerned, I always try to do my best. 至于工作，我总是竭尽全力地干。 I'm not concerned. 与我无关。 Everyone concerned in the murder case has been identified. 与凶杀案有牵连的人都已查明。 [短语] 1. be much concerned about 十分挂念 with a concerned air 用关心的态度

WELLPLAN Exercises


Exercise 2: Specifying Tubular Properties, and Working With Catalogs

1. Create a pipe grade named VMHCQ-125. This grade has the following properties:

• Section Type: Casing/Tubing

• Material: CS API 5CT

• Minimum Yield Strength: 125 kpsi

• Fatigue Endurance Limit: 25,000 psi

• UTS: 135 kpsi

2. Create a new Casing/Tubing Catalog with a name of your choice.

3. In the new casing/tubing catalog, create another pipe with the following properties:

• Nominal Diameter: 11 3/4”

• Nominal Weight: 65 lbs

• Grade: VMHCQ-125

• Body OD: 11.75”

• Body ID: 10.682 in

• Weight: 65 lbs.

• Pipe Type: Special

• Drift ID: 10.625 in

• Internal Yield: 9,940 psi

• Collapse Resistance: 6,540 psi

• Body Yield Strength: 2,352,010 lbf


WELLPLAN Exercises

• Linear Capacity: 0.1108 bbl/ft

• Closed End Displacement: 0.1341 bbl/ft

• Average Joint Length: 40.0 ft

• Wall Thickness: 87.5 %

• Plain End Cost: leave blank

4. Make a new Units set and name it ‘Class’. (Tools > Unit System) Base the new unit set on API units. In the Class unit set, make the following changes. Notice that the active Unit Set name is displayed in the bottom right corner of the Main Window. The active Unit Set is saved with the Case.

a) Use the unit ‘psi/ft’ for Mud Weight.

b) Has the unit for density changed? (Case > Fluid Editor)

c) Activate the API unit set. (Tools > Unit System.)

5. Import a catalog of diverter subs using the file DS Catalog.xml. To import the catalog, highlight Catalogs in the Well Explorer and then right-click. Select Import from the right-click menu. Review the information in the catalog. Diverter subs will be used in the Surge exercise.

user20

【dai‘verter】转换器 diverter sub 转换接头？？？？

user20

【serzhi】1. 波动 2. 脉动 3. 浪涌 4. 电涌 5. 冲击 6. 急变 7. 骤增 8. 滑脱 9. 打滑 10. 起伏 11. 颠簸 12. 纵摆 13. 喘振 14. 摇摆 15. 冲击波 16. 大浪 17. 波涛 18. 放松 19. 阵发 20. 激喷 21. 涌浪 22. 气象潮 23. 风暴潮 n. 1. 巨浪，波涛，汹涌，澎湃，滚流，起伏 the surge of the sea 海浪澎湃 a surge of smoke 浓烟滚滚 The sea was rolling in immense surges. 大海上浪涛汹涌。 2. （感情的）起伏，高涨 a surge of pity 油然而生的怜悯之心 A surge of anger rushed over him. 他勃然大怒。 3. 一阵（怒气，疼痛等）；一批（涌来的人）；一股（电流等） a surge of joy 喜从天降 4. [电]电流急冲，电涌 5. [海]缆绳滑脱；急速松缆，（绞盘急速松缆的）锥形部 6. [机]波动，湍振 vi. 1. 汹涌，澎湃，奔流，滚滚流动，起伏；（情绪）高涨，激动；蜂拥而来，涌出 A great wave surged over us. 巨浪打在我们身上。 A ship surges at anchor. 抛锚的船随波涛起伏。 Anger surged (up)within him. 他胸中怒气汹涌。 Blood surged to his face. 血涌到他的脸上。 The crowd surged out of the stadium. 人群从体育场涌出。 The stock market surged today. 今天股票上涨。 The floods surged over the valley. 洪水在山谷中汹涌流过。 The fans surged forward to see the movie star. 影迷们汹涌地冲奔去看那个影星。 2. [电]电涌，振荡 3. [海]缆绳滑脱；松缆 4. （车轮）空转打滑 vt. 使汹涌奔腾，急放

WELLPLAN Exercises


Exercise 3: Using the Case Menu

1. Define the hole section, including the last casing, liner, and the open hole section. (Case > Hole Section Editor) The well depth is 17,968 ft. Use 12,534 ft of 13 5/8”, 88.2 lb/ft, Q-125 casing with 17.5” effective hole diameter. Enter the 11 3/4”, 65 ppf, VMHCQ-125 liner. (You entered this in the last exercise.) Use Casing as the section type for liners. The effective hole diameter is 14.75. There is 1,837 ft of 12 1/4” open hole. Use .2 friction factor in cased hole and .3 in open hole. The open hole is gauge.

2. Define a simple drill string to become familiar with using the Case > String Editor.

• String Depth: 17,968 ft

• Drill Pipe: 12,589.24 ft, DP 5 in, 19.50 ppf, G, NC50(XH), P

• Heavy Weight: 60 ft, HW Grant Prideco, 5 in, 49.7 ppf

• Jar: 28 ft, JHM Bowen Hyd/Mech. 6 3/4” OD, 2.5” ID (Note: Adjust the jar length to 28 ft.)

• Heavy Weight: 300 ft, HW Grant Prideco, 5 in, 49.7 ppf

• Drill Collar: DC, 390 ft, 8” X 2.5”, 7 H-90

• Stabilizer: 5 ft, IBS, 10 5/8” FG, 8 X 2.5”

• Drill Collar: DC, 390 ft, 8” X 2.5”, 7 H-90


• Drill Collar (Non-mag): 31 ft, NDC 8” X 2.5”, 7 H-90


• MWD: 30 ft, MWD 8, 8 x 2.5 in

• Mud Motor: 30 ft, BHM 8, 8 x 2.5 in

• Sub: 3 ft, BS 6, 6 x 2 1/2 in

• Bit: Bi-Centered, 1 ft, 12.25” OD, 150 lbs, TFA = .614


WELLPLAN Exercises

3. Import the wellpath data. Use File > Import > Wellpath Data to import the file WP2003_5TrainingWellpath.TXT. Your instructor will tell you where the file is. The column order and units are: MD (ft), Inc (deg), and AZ (deg). (Note: It is important that you correctly specify column order and units.) Review the wellpath data using Case > Deviation > Wellpath Editor.

4. Enter mud properties on the Fluid Editor. Click the New button to enter data for a new fluid. (Case > Fluid Editor). After you are finished inputting fluid properties, click the Activate button to indicate you want this fluid used in the analysis. Use the following properties:

• Name: 15.1 ppg OBM

• Density: 15.1 ppg

• Type: Non Spacer

• Base Type: Oil

• PV: 24 cp at 120 degrees F

• YP: 7 lbf/100ft2 at 120 degrees F

• Rheological Model: Power Law

a) What are the calculated Fann dial readings?

5. Copy all pore pressure and fracture pressure from the file WPPoreFrac.xls. (Copy over all data (if any) already present in the pore pressure and fracture pressure spreadsheets.) Use CTRL-C and CTRL-V to copy and paste the data. In Excel, highlight all columns and then copy. In WELLPLAN, highlight the first row and use CTRL-V to paste the data.

6. Specify the geothermal gradient. The surface ambient temperature is 80 degree F, the mudline temperature is 40 degrees F, and the temperature at TD is 279.5 degrees F. What is the geothermal gradient?

7. Specify mud pump and other circulating system data. The surface equipment rated working pressure is 6,000 psi, and the surface

WELLPLAN Exercises


pressure loss is 100 psi. Define three pumps. Activate the 12-P-160 pump.

8. Create the following tabs (View > Tabs) by renaming or creating additional tabs. Use window splitters near the scrollbars to create window panes.

a) Create a tab titled Schematic. On that tab, create two vertical panes containing a Well Schematic-Full String and BHA-Not to Scale schematics. (One schematic in each pane.) Turn the header off in the Full String schematic.

b) Create a tab titled Editors. Create two horizontal panes on that tab. Open the Hole Section Editor in one pane and String Editor in the other pane.

c) Create a tab titled Deviation. Create two vertical panes. Open the Wellpath Editor in this tab.

d) Create a tab titled Plots. Open the Inclination plot in this tab.

9. This exercise step demonstrates the Freeze Line. (Later in this course, this feature will be applied to more meaningful sensitivity analysis.)

a) Using the Plot tab created in the previous step, place the cursor (arrow) on the data curve of the Inclination plot. Click the right mouse button, and select Freeze Line. Specify the color of the freeze line to be green and change the name of the curve.

b) Using the Deviation tab, change the inclination near 2527 ft to 50 deg. Notice the two curves visible at 2,527 ft on the Inclination plot.

c) Using the right mouse button, click on the previously frozen line. Select Hide Line. What happened to the line?

Name Vol/stk (gal/stk)

Max speed (spm)

Max Discharge Pressure (psi)

Horse Power (hp)

9-P-100 3.685 150 2790 900

10-P-130 3.984 140 3595 1170

12-P-160 6.433 120 3200 1440


WELLPLAN Exercises

d) Add a background logo to the plot. Right-click anywhere on the plot. Select the Background tab. Click the Bitmap button. Add the Halliburton logo to the plot. Your instructor can tell you the location of the file.

e) Close the plot.

10. Generate a survey Vertical Section plot. (View�!�Wellpath Plots�!�Vertical Section) Use the window splitters to give this plot the entire workspace on the Deviation tab.

11. Change the width of the data curve on this plot to 3. (Hint: Right-click on the curve and use right-click menu.)

12. Activate the Graphics Toolbar by clicking anywhere on the plot.

13. Use the Data Reader (third button from left on Graphics Toolbar) to determine the vertical section at TD. What is it?

14. Click on the Data Spreadsheet button (fourth button from the left on the Graphics Toolbar) to view X/Y coordinate data for the plot. Click the Arrow button (left button on Graphics Toolbar) to return to the plot view.

15. Click on the Properties button (right button on Graphics Toolbar) to open the Properties tabs. The following questions highlight the functionality of these tabs. (Hints: To easily view the changes to the plot, move the Properties tabs dialog box so that the plot is visible. Don’t forget to click the Apply button to implement changes.)

a) Using the Axis tab, Draw the X axis where Y = 0, and remove the tick marks from the Y axis.

b) Using the General/Grid tab, remove the grid lines from the plot.

c) Using the Labels tab, change the Y axis label to ‘True Vertical Depth’.

d) Using the Font tab, change the axis labels to green and italic.

e) Using the Markers tab, display data markers every 50 data points.

f) Using the Legend tab, turn off the legend.

16. Save this case.

WELLPLAN Exercises


17. Export this Case at the Company level using the filename of your choice.

18. Import the data file WELLPLANTraining2003_5.xml. This transfer file contains data you will be analyzing during this training course. For the rest of the course, you will be using the well LPN-004, wellbore ST1 in the site Kananga of the Full Feature Oil Co. company. This well is exactly like the one you just finished creating. To ensure that everyone has the same data, we are using the imported data rather than the data you entered.


WELLPLAN Exercises

Exercise 4: Using Torque Drag Analysis

Steps and Questions

1. Open the case titled TDA 14 3/4” Hole Section

2. Activate the Torque Drag Analysis module and select Drag Chart analysis mode.

3. Copy the assembly for the 12 1/4” Hole Section case in the well LPN-0042, wellbore ST1 plan P1 to the 14 3/4” Hole Section case. Change the string depth to 17,968 ft.

4. Review the hole section information and make a note of the open hole section measured depth interval. (Case > Hole Section)

5. Activate the 15.1 ppg OBM. (Case > Fluid Editor)

6. Open the template torquedrag.tpt. Review the different tabs. (File > Workspace > Open Template)

7. Apply tortuosity to the interval below 4,680 ft. This well is actually a sidetrack of another well. Tortuosity should only be applied to planned wellpath data. It should never be applied to actual survey data. In this example, there is actual survey data above 4,680 ft. Use the Random Inc Dependent Az method. Apply 0.30 between 4,680 ft and 7,000 ft. Below 7,000 ft, apply 0.50 degrees. Use a 100 ft Angle Change Period and interpolate every 30 ft. Review the tortured wellpath data to observe the revised inclinations.

8. Specify 50 kips traveling assembly weight. Include bending stress magnification (check the box), use 31 ft as the contact force normalization length, and analyze all mechanical limitations (again, check associated boxes). (Case > Torque Drag Setup)

9. Analyze the open hole interval (16,131 - 17968 ft) every 100 ft. Use 20 kip WOB and 2000 ft-lbf torque at bit for rotating on bottom operation. Also analysis rotating off bottom, and both tripping in and out. There is no rotation while tripping. (Parameter > Run Parameters)

10. Does the Drag Chart analysis predict any problems in this interval?

WELLPLAN Exercises


a) What does the Tension Point chart tell you? (View > Plot > Tension Point Chart or access the Drag Tension Point Chart tab)

b) What does the Torque Point Chart tell you? (View > Plot > Torque Point Chart or access the Drag Torque Chart tab)

c) What is the minimum WOB to avoid helical buckling while rotating on bottom? (View > Plot > Minimum WOB Chart or access the Drag Min WOB tab) Does the Drag Chart tell you where the string is buckling? If not, how could you find out where it is buckling?

11. Access the Normal Analysis mode. When using the Normal Analysis mode, where is the bit assumed to be?

12. Determine if buckling or fatigue is likely to occur for any selected operation mode. (View > Table > Summary Loads or click the Summary Load tab)

13. Where does the buckling occur while rotating on bottom? (View > Table > Load Data > Rotating On Bottom or click the Load/Stress Data tab)

14. Where is fatigue or tensile yield likely to occur:

a) While tripping out? (View > Table > Load Data > Tripping Out)

b) While rotation on bottom? (View > Table > Load Data > Rotating On Bottom)

c) While rotating off bottom? (View > Table > Load Data > Rotating Off Bottom)

15. How could we solve the fatigue and yield problems in the string? Try adding a 8050 ft section of S grade, 19.5 ppf drill pipe near the surface. Does that remove the yield or fatigue prediction?

16. If fatigue is still a problem, try using a different class or a different weight of S grade pipe near the surface.

17. If the buckling near the bit is still a problem, what could you do?


WELLPLAN Exercises

Answers

1. Double-click on the case name in the Well Explorer to open it.

2. Click the Torque Drag toolbar button, or use the Modules menu.

3. Using the Associated Data Viewer, right-click on the assembly you want to copy and select Copy from the menu. In the Well Explorer, highlight the case you want to copy the assembly to, right-click, and select Paste from the menu.

4. Use Case > Hole Section. The open hole interval is between 16, 131 and 17, 968 ft MD

5. Using Case > Fluid Editor, click once on the desired fluid to highlight it, then click the Activate button. Notice the tear drop next to the fluid indicating it is the active fluid.

6. Use File > Workspace > Open Template.

7. Use Case > Deviation > Wellpath Options.

WELLPLAN Exercises


8. Use Case > Torque Drag Setup


WELLPLAN Exercises

9. Use Parameter > Run Parameters

WELLPLAN Exercises


10. Does the Drag Chart analysis predict any problems in this interval?

a) Use View > Plot > Tension Point Chart or access the Drag Tension Point Chart tab

During a tripping in operation when the bit is at 17,431 ft the string is very close to buckling. Notice that this chart does not tell us anything about buckling while rotating.


WELLPLAN Exercises

b) Use View > Plot > Torque Point Chart or access the Drag Torque Chart tab.

This plot does not indicate that torque is going to be a problem over this interval. Notice that the make-up torque is always greater than any expected torque while rotating.

WELLPLAN Exercises


c) Use View > Plot > Minimum WOB Chart or access the Drag Min WOB tab. Does the Drag Chart tell you where the string is buckling? If not, how could you find out where it is buckling?

11. Access the Normal Analysis mode using the Mode drop-down list. The bit is assumed to be at the string depth indicated on the Case > String Editor spreadsheet.

Over the interval analyzed, we can determine from this plot that the minimum WOB to avoid buckling varies from slightly over 0 kips to slightly less than 10 kips WOB. We know we must be buckled, because we specified 20 kips WOB in the analysis parameters. To determine where it is buckling, you must use the Normal Analysis mode.


WELLPLAN Exercises

12. Use View > Table > Summary Loads or click the Summary Load tab.

13. Use View > Table > Load Data > Rotating On Bottom. Notice that buckling occurs near the bit. Scroll down the table and notice there is also fatigue and yield problems further up the string.

14. Where is fatigue or tensile yield likely to occur:

a) While tripping out, there are problems from the surface to 3,740 ft MD. Use View > Table > Load Data > Tripping Out.

b) While rotating on bottom, there are yield and fatigue issues from 3,000 - 4,400 ft and also around 650 ft MD. Use View > Table > Load Data > Rotating On Bottom.

c) While rotating off bottom, there are problems off and on from surface to 7,500 ft MD. Use View > Table > Load Data > Rotating Off Bottom.

Using this table, we can see there are a variety of problems including pipe yield, fatigue, failure, and buckling. Refer to the online help for a definition of codes.

WELLPLAN Exercises


15. Adding a 8,050 ft section of S grade, P, 19.5 ppf drill pipe near the surface resolved some, but not all of the problems.

16. Using 25.6 ppf, first class pipe solves the problem.

17. If the buckling near the bit is still a problem, you could reduce the WOB. You probably won’t get rid of all the buckling.


WELLPLAN Exercises

Exercise 5: Using Hydraulics Analysis

Steps and Questions

1. Open the Case HYD 14 3/4” Hole Section

2. Open the workspace template hyd_template.tpt.

3. Select the Hydraulics application, and Hole Cleaning - Operational from the Modules menu, or click the Hydraulics button and select Hole Cleaning - Operational from the Mode drop-down list.

4. The pressure response data for the mud motor in the current work string is 350 psi loss at 530 gpm and 350 psi loss at 900 gpm. Add this to the mud motor description.

5. Set the string depth to 17,968 ft to put the bit “on-bottom”. (Case !�String Editor)

6. What are the bit nozzle sizes? (Case !�String Editor)

7. Use the Circulating System dialog to answer the following questions, or to perform the following steps. (Case !�Circulating System)

a) What is the maximum working pressure specified? (Case !�Circulating System�!�Surface Equipment tab)

b) Specify surface pressure loss of 100 psi.

c) Mark the pump name 12-P-160 the active pump. (Case !�Circulating System�!�Mud Pumps tab)

8. Specify the cuttings transport analysis parameters. (Parameter > Transport Analysis Data)

• ROP: 25 ft/hr

• Rotary Speed: 90 rpm

• Pump Rate: 400 gpm

WELLPLAN Exercises


• Cuttings Diameter: 0.125 in

• Cuttings Density: 2.500 sg

• Bed Porosity: 36.00 %

• MD Calculation Interval: 100 ft

9. Determine the minimum flow rate required to clean the wellbore. (View > Plot > Operational)

10. What is the percentage of cuttings suspended compared to the total volume of cuttings?

11. Change the yield point to 15 lbf/100 ft 2. Did this impact the required minimum flow rate and the bed height?

12. Determine the maximum flow rate. Analyze every 25 gpm between 400 and 600 gpm. Use the Annular Velocity Analysis. (Modules !�Hydraulics !�Annular Velocity) (Parameter !�Rates) Answer the following questions pertaining to this analysis.

a) Use the Annular Velocity (View !�Plot !�Annular Velocity) plot to determine which flow rates result in non-laminar flow, and where does this flow regime occur?

b) What is the critical annular pump rate inside the casing? What is the critical annular velocity inside the liner? (View !�Plot !�Annular Pump Rate)

13. Select the Pressure: Pump Rate Range (Modules !�Hydraulics !�Pressure: Pump Rate Range) analysis mode.

a) Analyze flow rates between 400 gpm to 600 gpm in 25 gpm increments. Default Pumping Constraints from the Pump Data. Include tool joint pressure losses. (Parameter !�Rates)

b) Specify ECD calculations to be performed at the casing shoe (16,132 ft) and at TD (17,968 ft). (Parameter !�ECD Depths)

c) How is the maximum pump pressure calculated when it is defaulted from the pump data and there is more than one active pump? (Hint: Use the online help.)

d) Generate a Pressure Loss report.(View !�Report !�Pressure Loss) At 425 gpm, what is the pressure loss gradient (psi/ft)


WELLPLAN Exercises

down the inside of the drill pipe? (Hint: You can not read this directly.) Is there turbulence in the annulus at this flow rate? Record the bit, string, and annular pressure losses.

e) Generate a Pressure Loss plot. (View !�Plot !�Pressure Loss) Use the Data Reader to determine the bit, string and annular pressure losses at 425 gpm. Compare these values against those in the Pressure Loss report. Do they match?

14. Perform Optimization Planning analysis to optimize bit hydraulics. (Modules !�Hydraulics !�Optimization Planning)

a) Select the Opti Plan tab.

b) Specify the analysis parameters. Default pump data. Specify a minimum nozzle size of 10/32nds and specify that 8 nozzles be used. Allow 60% pressure loss at the bit. Specify 80 ft/min as the minimum annular velocity. Include tool joint pressure losses, and do not allow turbulent flow in the annulus. (Parameter !�Solution Constraints.)

c) What is the pump rate and nozzle sizes to maximize bit hydraulics if we want an HSI between 2 and 6?

d) Close the Solution Constraints dialog.

15. Will the pump rate determined in the previous step clean the hole?

16. Can we pump at this pump rate using the nozzle sizes identified? Use Pressure: Pump Rate Range analysis and refer to the View > Plot > Pressure Loss plot.

17. We need to increase the pump pressure. Leave the current Pressure Loss plot open. Activate the 10-P-130 pump in addition to the 12-P-160 pump. Did this help? Why or why not? (Hint: Refer to online help.)

18. De-activate the 10-P-130 pump. Change the liner size on the 12-P-160 pump. Use a 5.5” liner size with a maximum discharge pressure of 5000 psi and 3.702 gal vol/stk. Now can we pump at the required pump rate to optimize hydraulics?

19. Perform a Swab/Surge Tripping Schedule (Modules !�Hydraulics !�Swab/Surge Tripping Schedule) analysis.

WELLPLAN Exercises


a) Analyze closed and open end for both surge and swab scenarios. Use 523 gpm for the flow rate for the open ended swab and surge analysis. Use a 90 ft stand length and .5 ppg delta P. Use local nozzles (8X10). (Parameter !�Operations Data)

b) Generate a Swab/Surge (View !�Report !�Swab/Surge) report. For the closed end swab scenario, how fast can the first few stands be tripped without causing a change greater than 0.5 ppg?

20. Perform a Swab/Surge Pressure and ECD analysis using the same data as in the previous step. Generate a Swab Closed End plot (View !�Plot !�Swab Closed End). What is the ECD at the casing shoe for a 50 sec/stand trip speed?

Answers

1. Open the Case HYD 14 3/4” Hole Section by double-clicking on it in the Well Explorer.

2. Open the workspace template hyd_template.tpt. Use File > Workspace > Open Template.

3. Select the Hydraulics application, and Hole Cleaning - Operational from the Modules menu, or click the Hydraulics button to select the Hydraulics application, and select Hole Cleaning - Operational from the Mode drop-down list.


WELLPLAN Exercises

4. Use Case > String Editor. Highlight the row associated with the mud motor. Use String > Data to add the mud motor data.

5. Use Case !�String Editor.

6. Use Case !�String Editor.

7. Use the Circulating System dialog to answer the following questions, or to perform the following steps. (Case !�Circulating System)

Set the string depth to 17,968 ft to put the bit “on-bottom”.

WELLPLAN Exercises


a) What is the maximum working pressure specified? Use Case !�Circulating System�!�Surface Equipment tab.

b) Specify surface pressure loss of 100 psi.

c) Use Case !�Circulating System�!�Mud Pumps tab.

Maximum working pressure

Check the Active box to make the pump the active pump.


WELLPLAN Exercises

8. Specify the cuttings transport analysis parameters using Parameter > Transport Analysis Data.

WELLPLAN Exercises


9. Determine the minimum flow rate required to clean the wellbore using View > Plot > Operational. Use the Data Reader to read the minimum flowrate.

10. The percentage of cuttings suspended is less that one percent compared to the total volume of cuttings, which is almost 6.5%.

Notice there is a bed height of approximately 1.5” when the flowrate is 400 gpm.

The minimum flowrate to avoid a cuttings bed is 451.7 gpm.


WELLPLAN Exercises

11. Use the Case > Fluid Editor to change the yield point to 15 lbf/100 ft 2. Yes, this reduced the required minimum flow rate and the predicted bed height.

12. To determine the maximum flow rate, use the Annular Velocity Analysis. Use Parameter !�Rates to specify range of flowrates to analyze.

a) Use the Annular Velocity (View !�Plot !�Annular Velocity) plot to determine which flow rates result in non-laminar flow. In

Minimum flowrate required using adjusted yield point.

WELLPLAN Exercises


this example, turbulent flow occurs somewhere between 525 and 550 gpm.

This plot displays the annular velocity in each section of the well for each flowrate specified on the Rates dialog.


WELLPLAN Exercises

b) What is the critical annular pump rate inside the casing? What is the critical annular velocity inside the liner? Use View !�Plot !�Annular Pump Rate.

13. Select the Pressure: Pump Rate Range (Modules !�Hydraulics !�Pressure: Pump Rate Range) analysis mode.

Critical pump rate in the 13 5/8” casing is 667 gpm.

Critical pump rate in the 11 3/4” liner is 532.7 gpm.

WELLPLAN Exercises


a) Analyze flow rates between 400 gpm to 600 gpm in 25 gpm increments. Default Pumping Constraints from the Pump Data. Include tool joint pressure losses. (Parameter !�Rates)

b) Specify ECD calculations to be performed at the casing shoe (16,132 ft) and at TD (17,968 ft). (Parameter !�ECD Depths)

c) If you have more than one active pump specified on the Circulating System/Mud Pumps tab, the Maximum Pump Pressure will be set equal to the minimum value entered for Maximum Discharge Pressure for any of the active pumps.

d) Generate a Pressure Loss report.(View !�Report !�Pressure Loss) At 425 gpm, read the pressure loss inside the drillpipe. Then divide this pressure loss by the total length of the drillpipe. Refer to Case > String Editor for the length of the drillpipe. There is no turbulence in the annulus. Refer to the Annulus section of the report.

e) Generate a Pressure Loss plot. (View !�Plot !�Pressure Loss) Use the Data Reader to determine the bit, string and annular pressure losses at 425 gpm. Yes, they match. Notice the bit pressure loss is low.

14. Perform Optimization Planning analysis to optimize bit hydraulics. (Modules !�Hydraulics !�Optimization Planning)

a) Because of the template you imported, the Opti Plan tab is already setup to include the Optimization Planning analysis dialog (Solution Constraints).

Click Default from Pump Data to use data from the pumps marked as active on the Case > Circulating System > Mud Pumps tab.


WELLPLAN Exercises

b) Specify the analysis parameters. Default pump data. Specify a minimum nozzle size of 10/32nds and specify that 8 nozzles be used. Allow 60% pressure loss at the bit. Specify 80 ft/min as the minimum annular velocity. Include tool joint pressure losses, and do not allow turbulent flow in the annulus. (Parameter !�Solution Constraints.)

c) A pump rate of 532.2 and nozzle sizes of 8 X 10/32nds is required to maximize bit hydraulics if we want an HSI between 2 and 6.

d) Close the Solution Constraints dialog.

15. Yes, this pump rate will clean the hole. We determined that 426 gpm is required for hole cleaning.

WELLPLAN Exercises


16. Use Pressure: Pump Rate Range analysis and refer to the View > Plot > Pressure Loss plot.

17. We need to increase the pump pressure. Leave the current Pressure Loss plot open. Activate the 10-P-130 pump in addition to the 12-P-160 pump. This doesn’t help because we are limited by the lesser pressure of the two active pumps.

18. De-activate the 10-P-130 pump. Change the liner size on the 12-P-160 pump. Use a 5.5” liner size with a maximum discharge pressure of 5000 psi and 3.702 gal vol/stk. Don’t forget to reselect the active

At 532 gpm, the system pressure loss is greater than the pressure the pump can produce. Therefore, we can’t p[ump at this rate using the pump we have active.


WELLPLAN Exercises

pump information on the Parameter >Rates dialog by clicking the Default from Pump Data button.

19. Perform a Swab/Surge Tripping Schedule (Modules !�Hydraulics !�Swab/Surge Tripping Schedule) analysis.

a) Analyze closed and open end for both surge and swab scenarios. Use 523 gpm for the flow rate for the open ended swab and surge

Add another row to indicate the pump with the new liner size.

It is close. You probably want a to try another liner size.

WELLPLAN Exercises


analysis. Use a 90 ft stand length. Use local nozzles. (Parameter !�Operations Data)

b) Generate a Swab/Surge (View !�Report !�Swab/Surge) report. For the closed end swab scenario, the first 101 stands can be tripped at 20 sec per stand.

20. Perform a Swab/Surge Pressure and ECD analysis using the same data as in the previous step. Generate a Swab Closed End plot


WELLPLAN Exercises

(View !�Plot !�Swab Closed End). The ECD at the casing shoe for a 50 sec/stand trip speed is 15.01 ppg.

WELLPLAN Exercises


Exercise 6: Using Well Control Analysis

Steps and Questions

1. Open the Case WCN 14 3/4” Hole Section.

2. Select the Well Control application, and Expected Influx Volume from the Modules menu, or click the Well Control button and select Expected Influx Volume from the Mode drop-down list.

3. Review the Geothermal Gradient.

4. Specify the use of the Steady-State Circulation Model for the well control analysis. (Parameter > Temperature Distribution) Specify a flow rate of 500 gpm and a flow line temperature of 104 degrees Fahrenheit. Click OK.

5. Generate a Temperature Distribution Plot. (View > Plot�!�Temperature Distribution) Answer the following questions.

a) Why does the geothermal gradient profile change slope?

b) What do the annulus and string curves represent?

6. To determine the type of kick encountered, specify a Circulation Flowrate of 520 gpm and a Kick Interval Gradient of 0.80. (Parameter > Kick Class Determination) Click Apply and answer the following questions.

a) What type of kick would occur in this situation? Why?

b) What is the difference between the interval pressure where the kick occurred and the static BHP (psi)?

7. After the Kick Class has been determined, you can calculate the estimated influx volume.

a) Specify that the kick detection equipment is based on flowrate, and can detect a 40 gpm flowrate change. (Parameter > Influx Volume Estimation > Kick Detection Method tab)

b) Specify the reservoir properties. The porosity of the reservoir is 25%, the permeability is 10 md, the reservoir thickness is 100 ft


WELLPLAN Exercises

and the rate of penetration is 25 ft/hr. (Parameter > Influx Volume Estimation > Reservoir tab)

c) Crew reaction times have been entered for you. What is the total crew reaction time specified from detection of kick up to and including closing the choke? This is modeling a “soft shut-in”. How could a “hard shut-in” be modeled? (Parameter > Influx Volume Estimation > Reaction Times tab)

d) In this scenario, what size influx was predicted? (Parameter > Influx Volume Estimation > Results tab)

e) Change the detectable flowrate variation to 20 gpm. Click Apply to process the changes. Now what is the predicted influx size?

8. Now that we know the expected influx volume, we will analyze the pressures associated with a kick of this size. Select Kick Tolerance from the Mode drop-down list. First, we must finish entering data required to define the current kick situation.

9. Use the Circulating System dialog (Case > Circulating System) to answer to following questions, or perform the following steps.

a) What is the maximum working pressure specified on the Surface Equipment tab?

b) On the Mud Pumps tab, mark the pump name 12-P-160 with the 3.702 gal/stk volume the active pump.

c) Click OK to activate your changes and close the dialog.

10. Configure well control options. (Case > Well Control Setup) Specify the BOP rating to be 10,000 psi, and the casing burst rating to be 6,540 psi. Use an 80% casing burst safety factor. We will be using the “Wait and Weight” method to kill the well. A leak off test was run with 15.1 lb mud. The leak off pressure was 1,900 psi. (Case > Well Control Setup�!�Operational tab) Click Apply.

11. Use the Steady-State Circulation temperature model (Parameter !�Temperature Distribution) to estimate the influx volume. The flowline mud temperature is 104 degrees Fahrenheit, the flowrate is 500 gpm and the mud density is 15.1 ppg.

a) What flowrate is represented on this dialog? (Hint: Use the Help.)

WELLPLAN Exercises


b) Click OK to activate your changes and close the dialog.

12. The Kick Class was determined earlier in this exercise while estimating the influx volume. What Circulation Flowrate is entered (Parameter > Kick Class Determination) dialog? Is it the kill circulation rate?

13. Now we must specify information that will be used to simulate and analyze the results of circulating the influx. (Parameter > Kick Tolerance) Assume a gas influx. Specify a kill rate of 130 gpm, with a kill mud gradient of .55 psi/ft. We will be circulating a 14 bbl influx. We are interested in analyzing the situation at the casing shoe (16,131 ft). We are planning our next casing shoe at 17,968 ft. Click OK to accept your changes and close the dialog.

a) What is the correct interval to analyze if we want to check the next casing shoe depth of 17,968 ft?

14. Answer the following questions pertaining to the results of the Kick Tolerance analysis. All analysis results (plots and schematics) are available via the View menu.

a) Determine the maximum annular pressure to expect at the depth of interest. (View > Plot�> Pressure at Depth) Use the data reader to determine the maximum pressure. What is the maximum pressure? What volume of kill mud had been pumped when this pressure occurred? Why doesn’t the curve have a constant slope?

b) Click the right mouse button on the curve and select Freeze Line. (Click the arrow on the Graphics Toolbar to exit Data Reader mode.) Change the color of the curve to purple. Change the Legend description to “Max Pressure at Shoe”. Click OK. Do not close the plot.

c) Change the depth of interest to 17,000 ft. (Parameter > Kick Tolerance) Determine the maximum pressure to expect at 17,000 ft as the kick is circulated out. (View > Plot > Pressure at Depth) What is the maximum pressure? Can you still see the curve line for the maximum pressure at 16,131 ft?

d) Determine the maximum pressure resulting from the specified influx volume.(View > Plot�> Maximum Pressure) Will the casing shoe be able to withstand the maximum pressure resulting from this size of kick?


WELLPLAN Exercises

e) Would the current casing shoe depth (16,131 ft) suffice if there was a full gas evacuation? (View > Plot�> Full Evacuation to Gas)

15. Much of the information required to generate a Kill Sheet can be entered prior to taking a kick. Select Kill Sheet from the Mode drop-down list. Enter the following information to be prepared if a kick should occur.

a) Generating a Kill Sheet requires input on the Well Control Setup dialog. Much of this information was input earlier in this exercise. However, slow pump data must also be entered. Please specify the following slow pump information.

b) Specify the use of pump 12-P-160 at 30 spm. Use the Select Pump/Kill Speed button on the (Parameter > Kill Sheet, Pumps Tab). Click Apply.

c) Enter the string volume. Use the Default from Editors button (Parameter > Kill Sheet, String Tab). Click Apply. If a string was not entered on the String Editor, you would have to input this information yourself.

d) Enter the annulus volume. Use the Default from Editors button (Parameter > Kill Sheet, Annulus Tab). Click Apply. If a string and wellbore were not entered on the String Editor and the Hole Section Editor, you would have to input this information yourself.

e) Specify information regarding weighting up the mud. (Parameter > Kill Sheet > Weight Up Tab) The mud tank volume is 800 bbls. Mixing capacity is assumed to be 50 lb/min. Barite is the weighting material used in this example. The specific gravity of barite is 4.2, and is available in 94 lb bags. Click Apply.

16. When a kick is taken, information regarding the kick must be entered on the Parameter > Kill Sheet > Kick Parameters Tab. For this exercise, assume a 25 bbl pit gain at 11,029 ft. The Shut-In Drill Pipe Pressure is 520 psi, the Shut-In Casing Pressure is

Pump Name Speed (spm) Pressure (psi)

12-P-160 30 400

12-P-160 60 700

WELLPLAN Exercises


720 psi, the Overkill Pressure is 100 psi, and the Trip Margin is .5 ppg. Click OK to activate your entries and to close the dialog.

17. Use the Kill Sheet report or plot to answer the following questions.

a) How many sacks of weighting material will be required to weight up the mud?

b) Determine how many strokes are required to fill the string with kill mud? How many minutes will this take? (View > Report�> Kill Sheet)

c) Determine the standpipe pressure after the string is filled with kill mud. (View > Plot�> Kill Sheet)

Answers

1. Double-click on the desired case within the Well Explorer to open it.

2. Click on the Well Control button to select the Well Control module. Select Expected Influx Volume from the Mode drop-down list.

3. Use the Case > Geothermal Gradient tabs.

4.

Click the Steady State Circulation button to use that model.

You do not need to specify the mud density because it defaults from the Case > Fluid Editor.


WELLPLAN Exercises

5.

a) The Geothermal Gradient profile changes slope because the plot is MD, not TVD.

b) The annulus and string curves represent the steady state circulating temperature in the annulus and the string.

6.

a) A kick while drilling would occur in this situation because the pore pressure is greater than the circulating BHP.

b) The difference between the interval pressure where the kick occurred and the static BHP is 274.2 psi.

The Quick Look section displays the results.

WELLPLAN Exercises


7. Use the Parameter > Influx Volume Estimation tabs to determine the influx volume.

a)

b)

c) Total crew reaction time is 5.6 minutes. A “hard shut-in” could be modeled by setting some of the reaction times to zero.

Use Parameter > Influx Volume Estimation > Kick Detection Method tab to specify the kick detection equipment.

Use Parameter > Influx Volume Estimation > Reservoir tab to specify the kick detection equipment.

Add the reaction times to determine the total crew reaction time.


WELLPLAN Exercises

d)

e)

8. Select Kick Tolerance from the Mode drop-down list.

9. Use the Case > Circulating System tabs.

a) 6000 psi

An 58.3 bbl influx is predicted.

A 14.0 bbl influx is predicted when the detection flowrate is reduced to 20 gpm.

WELLPLAN Exercises


b)

10. Use the Case > Well Control Setup > Operational tab to configure some of the analysis options.

11.

Check this box to make the 12-P-160 with 3.702 gal/stk volume the active pump.


WELLPLAN Exercises

a) The flow rate on this dialog is the average flow rate over the last 24 hours.

12.

13.

a) The depth interval to check to reach the casing shoe at 17,968 ft would be 1,837 ft. (17,968 - 16,131)

14.

a) The maximum pressure is 12,779.8 psi when 2 bbls have been pumped. The curve does not have a constant slope because it

The circulation flowrate is the flowrate during drilling just prior to taking the influx. It is not the circulation kill rate.

WELLPLAN Exercises


reflects the changes in pressure resulting from changing fluid lengths in the different annular sections.

b)


WELLPLAN Exercises

c) The maximum pressure is 13,462 psi when 2 bbls have been pumped. Yes, you can still see the curve for 16,131 ft.

d)

Yes, the shoe can withstand the kick of 14 bbls.

WELLPLAN Exercises


e)

15. Select Kill Sheet from the Mode drop-down list.

a)

The casing shoe could not withstand a full evacuation to gas.

Use Case > Well Control Setup > Slow Pumps to specify slow pump information.


WELLPLAN Exercises

b)

Click the Select Pump/Kill Speed button to select the pump speed from the dialog that appears.

The Select Pump/Kill Speed dialog appears when the Select Pump/Kill Speed button is clicked.

WELLPLAN Exercises


c)

d)

Click the Default from Editors button to use the data entered on the Case > String and Case > Hole Section editors.

Click the Default from Editors button to use the data entered on the Case > String and Case > Hole Section editors.


WELLPLAN Exercises

e)

16.

17. Use the View > Report > Kill Sheet report or the View > Plot > Kill Graph.

WELLPLAN Exercises


a) Use View > Report > Kill Sheet.

b)

c)

1486.6 sacks are required.

2147 strokes are required to fill the string. It will take 71.6 minutes.

The standpipe pressure is 416 psi.


WELLPLAN Exercises

Exercise 7: Using Surge Analysis

Note

Because of class time constraints, we will not be using the low clearance option during the course because of the length of time required to perform the calculations when the low clearance option is used. However, you should consider using this option in the future. The low clearance analysis is an improved analysis model that tightly couples the fluid forces with the axial forces. This analysis option results in more reliable results, particularly when the clearance is less than 0.5 inches and/or the analysis interval is long. The low clearance analysis can take a considerable amount of time to calculate. Therefore, when you use this analysis option, it is recommended that you analyze one operation at a time, and that you limit the analysis to two moving pipe depths.

Steps and Questions

1. Open the Case SRG 11 3/4” Liner.

2. Click the Surge button to start the Surge module.

3. Assume the well has only one formation from the surface to TD. This formation has an Elastic Modulus of 1,500,000 and a Poisson’s Ratio of 0.3. (Case�!�Formation Properties)

4. The cement set behind the casing has an Elastic Modulus of 3,000,000 and a Poisson’s Ratio of 0.35. (Case > Cement Properties)

a) Why don’t you specify the cement properties using the Case > Fluid Editor?

5. Use 13.35 ppg OBM. This mud has already been defined. There is no pumping while tripping.

6. Define a surge operation. Name it Run Liner.

• Specify Depths of Interest to be at 12,834 ft (casing shoe) and at 16,131 ft (TD). Will these depths of interest be used for all operations? You should also analyze any weak formations. Are there any you should consider?

WELLPLAN Exercises


• Assume you want to analyze when the pipe is at the previous casing shoe (12,834 ft), and near TD (use 16,000 ft). You may also want to consider analyzing when the pipe is at the weak zone.

• To define analysis parameters for this operation, click on the row number for the operation titled Run Liner to highlight the row. Next, click the Details button.

• Enter a pipe stand length of 90 ft, pipe acceleration of 1 ft/sec2, and pipe deceleration of 1 ft/sec2. Do not use a float. Do not check the Optimize Trip Time box. Why don’t you need to enter a Maximum Trip Speed? (Parameter ! Operations Data�!�Details Button�!�Analysis Conditions)

• Specify a pipe speed of 100 ft/min for cased hole and open hole. (Parameter ! Operations Data !�Details Button�!�Analysis Depths)

7. Is this operation likely to fracture the formation?

8. To avoid fracturing the formation, you may want to use different trip speeds. Determine the safe tripping speeds using Optimize Trip Time. Use a maximum trip speed of 180 ft/min.

9. You may also want to consider using a diverter sub to avoid fracturing the weak zone. Uncheck the Optimize Trip Time box and add a divertor sub to the workstring. Use the diverter sub in the catalog that has the 0.589 flow area. Does the diverter sub reduce the surge pressure enough to avoid fracturing the weak zone?

10. Define a swab operation. Name it Pull Liner.

• Use the same moving pipe depths as you did for the surge analysis.

• Use the same depths of interest as you did for the surge analysis. • To define analysis parameters for this operation, click on the row

number for the operation titled Pull Liner to highlight the row. Next, click the Details button.

• Enter a pipe stand length of 90 ft, pipe acceleration of 1 ft/sec2, and pipe deceleration of 1 ft/sec2. Use a float with zero percent open area. Do not check the Optimize Trip Time box. Why don’t you need to enter a Maximum Trip Speed? (Parameter ! Operations Data�!�Details Button�!�Analysis Conditions)

• Specify a pipe speed of 60 ft/min for cased hole and open hole. (Parameter ! Operations Data !�Details Button�!�Analysis Depths)


WELLPLAN Exercises

11. Is this operation likely to cause a kick?

12. Assume the float has a 25% open area. Compare the results for depth of interest 16,131 ft with the float having 0% open area. To easily compare the results, use the Freeze Line feature. After you finish comparing results, right-click on the “frozen” lines and remove them.

13. After the 11 3/4” liner is cemented, is there any problems tripping in, tripping out, or reciprocating the 12 1/4” string used to drill the next hole section? Use the case 12 1/4” Tripping Ops. The surge and swab operations have been defined for you. Define a reciprocation operation. Name it Reciprocate. (Parameter ! Operations Data) To define analysis parameters for this operation, click on the row number for the operation titled Reciprocate to highlight the row. Next, click the Details button.

a) Enter a pipe acceleration of 1 ft/sec2, and pipe deceleration of 1 ft/sec2. Do not check the Float Used in Workstring box. (Parameter ! Operations Data�!�Details Button�!�Analysis Conditions)

b) Specify a Stroke Length of 31 ft, and a Stroke Rate of 5 spm. Use 15.1 ppg OBM with a Flow Rate of 400 gpm. (Parameter !Operations Data�!�Details Button�!�Reciprocation Data)

14. Is it likely that these operations will cause any problems over this drilling interval?

Answers

1. Double-click on the case you want to open in the Well Explorer.

2. Click on the Surge button to select the Surge module.

3.

Enter the formation properties based on true vertical depth (TVD). These data are used to calculate the compressibility of the formation.

WELLPLAN Exercises


4.

a) Because the cement is already set. The Case > Cement Properties dialog is used to specify the properties of set cement. The Case > Fluid Editor is not.

5. Use Case > Fluid Editor to activate the 13.35 ppg WBM if necessary. There is no need to use the Parameter > Job Data dialog because there is no pumping while tripping.


WELLPLAN Exercises

6. Determine the weak zone by referring to Case > Fracture Gradient.

Notice the weak zone at 13,253 ft vertical depth (not measured depth).

WELLPLAN Exercises


Define a surge operation using Parameter > Operations Data.

• Use Parameter ! Operations Data�!�Details Button�!�Analysis Conditions.

• Use Parameter ! Operations Data !�Details Button�!�Analysis Depths.

Highlight the row and then click Details to input details about the operation.

You don’t need to specify the last casing shoe or TD as a Depth of Interest because they are automatically added.

You don’t need to specify a maximum trip speed because you are not optimizing trip times.


WELLPLAN Exercises

a) Analysis Depths default from the moving pipe depths specified on the Surge Operations Data dialog.

7. Use View > Single Operation Plot > Transient Response Plot. Use Data Selection to view the results at the weak zone.

8. Check the Optimize Trip Time box on the Analysis Details tab to indicate you want to have WELLPLAN determine the trip speeds to avoid high surge pressures.

Yes, it is likely the weak zone will fracture. Notice the surge pressure are predicted to be greater than the fracture pressure at the depth of interest.

WELLPLAN Exercises


Using the optimized trip time, the pressure no longer exceed the fracture gradient.

Notice the various calculated trip speeds. You would want to use the minimum of these trip speeds to avoid fracturing the weak zone.


WELLPLAN Exercises

9. Use Case > String Editor to add the diverter sub.

10. Define a swab operation using Parameter > Operations Data.

Using a diverter sub, the pressure do not exceed the fracture pressure of the weak zone.

Highlight the row and then click Details to input details about the operation.

WELLPLAN Exercises


• Use Parameter ! Operations Data�!�Details Button�!�Analysis Conditions.

• Use Parameter ! Operations Data !�Details Button�!�Analysis Depths.

11. Use View > Single Operation Plot > Transient Response Plot.

Notice that the pressure is very close to the pore pressure at 12,834 ft when the moving pipe is also at that depth.


WELLPLAN Exercises

Right-click on the plot and use the Data Selection dialog to select the depth of interest to be 13,627 ft.

Right-click on the plot and use the Data Selection dialog to select the depth of interest to be 16131 ft.

Notice the pressure is not below the pore pressure at 13,627 at any moving pipe depth.

Notice the pressure is below the pore pressure at 16,131 ft when the moving pipe is at 13,627 ft and 12,834 ft.

WELLPLAN Exercises


12.

13. Use Parameter > Operations Data.

8. Use Parameter > Operations Data. Yes, the Depths of Interest are used for all operations.

Using a float with 25% open area significantly reduces the pressure.

To analyze when the bit or bottom of the string is at a certain depth, enter the depth as a Moving Pipe Depth.


WELLPLAN Exercises

9.

a) The Maximum Trip Speed only applies to operations that will be optimized on trip time. (i.e. those operations that have the Optimize Trip Time box checked.)

b)

Highlight the operation you want to define details for and then click the Details button.

WELLPLAN Exercises


c) Analysis Depths default from the Moving Pipe Depths. (Parameter�!�Operations Data�tab)

10.

a)

b)



WELLPLAN Exercises

11.

a)

b)


WELLPLAN Exercises


12. Right-click anywhere on the plot to display the Data Selection dialog.

Select Trip In from the list.

Use data reader to read maximum surge pressure at the shoe of 5,326 psi when the bit is at the shoe.

Use Data Reader to determine the pressure.


WELLPLAN Exercises

13.

a)

b)

14. Use View > Multiple Operation Plot > Transient Response to view the pressures for each operation at each depth of interest for each moving pipe depth. Right-click and use Data Selection to select the various moving pipe depth and depth of interest combinations. None of the operations predict pressures likely to fracture the formation or cause a kick.

WELLPLAN Exercises


Exercise 8: Using Cementing - OptiCem

Steps and Questions

1. Open the Case CMT 11 3/4” Liner.

2. Select the Cementing-OptiCem module, and Wellbore Simulator from the Modules menu, or click the Cementing-OptiCem

button and select Wellbore Simulator from the Mode drop-down list.

3. Specify a 15% volume excess in the open hole for cement job planning. (Case�!�Hole Section Editor)

4. You will be using the following fluids. Specify or review the fluid data using the Fluid Editor. (Case�!�Fluid Editor)

a) Review the properties of the fluid titled 13.35 ppg OBM.

b) Type in data for a spacer. Name the spacer 12 ppg Spacer. It is an oil based, Bingham Plastic fluid, with a density of 12 ppg. At 70 deg, the PV is 24, and the YP is 12 lbf/100ft2.

c) Type in data for the lead cement. Name the cement 12.5 ppg Lead. It is a Bingham Plastic fluid, with a density of 12.5, a water requirement 12.81 gal/sack, and a yield of 2.12 ft3/sack. At 70 deg, the following Fann data readings apply: at 600 rpm the dial reading is 54.4 deg, at 300 rpm the dial reading is 30.42 deg.

d) Type in data for the tail slurry. Name the cement 15.6 Tail. It is a Bingham Plastic fluid, with a density of 15.6, a water requirement 4.98 gal/sack, and a yield of 1.16 ft3/sack. At 95 deg, the following Fann data readings apply: at 300 rpm the dial reading is 150 deg, at 200 rpm the dial reading is 105 deg, and at 100 rpm the dial reading is 59.5 deg. At a temperature of 149 deg the following Fann data readings apply: at 300 rpm the dial reading is 130 deg, at 200 rpm the dial reading is 94.5 deg and at 100 rpm the dial reading is 53.5 deg. At 185 deg, the following Fann data readings apply: at 300 rpm the dial reading is 83 deg, at 200 rpm the dial reading is 57.5 deg and at 100 rpm the dial reading is 31.5 deg.


WELLPLAN Exercises

5. Copy the fracture gradient data for this case from the case TDA 14 3/4” Hole Section. (Case�!�Frac Gradient) Is there a weak zone? If so, what is the vertical depth at the weak zone?

6. Specify the following cement job data using Parameter�!�Job Data.

• As the wellbore fluid, use the 13.35 ppg OBM. Pump at a 12 bbl/min rate.

• Use 200 bbls of the 12 ppg Spacer as a spacer. Pump the spacer at 8 bbl/min.

• Pump the 12.5 ppg Lead cement at a rate of 8 bbl/min. The top of the lead cement should be at 12,534 ft.

• Pump 400 ft of the 15.6 Tail slurry at a rate of 4 bbl/min.

• Use 80 ft of the tail slurry as the shoe slurry. Pump it at a rate of 4 bbl/min.

• Displace the cement with the 13.35 ppg OBM mud pumped at 12 bbl/min.

• Use 14.7 psi for the Back Pressure and use 0 bbl Return Volume.

• Do not automatically adjust the rates, use foamed cement, or disable auto-displacement calculations. (Don’t check any of these boxes.)

• Use the lead cement as the tracer fluid.

a) Why are we using 14.7 psi for the back pressure?

7. We will use TD of this hole section (16,131 ft MD) as the reservoir zone of interest and the fracture zone (weak zone) of interest is 13,627 ft MD. Do not take returns at the sea floor. Use a BHCT of 205.3 deg F, a surface temperature of 80 deg F and a mud outlet temperature of 120 deg F. (Parameter�!�Additional Data)

8. Do the circulating pressures during the cement job exceed the fracture pressure? (View�!�Plot�!�Circ Pres and Den - Frac Zone)

WELLPLAN Exercises


9. Is it possible to take a kick during the cement job or to fracture the weak zone during the job? (View�!�Plot�!�Downhole Pressure Profiles)

10. Does “freefall” occur during the job? (View�!�Plot�!�Comparison of Rates In and Out)

11. What is the maximum calculated wellhead surface pressure and when during the job does it occur? (View�!�Plot�!�Calculated Wellhead/Surface Pressure)

12. Using the Fluid Animation Schematic, what is the pressure in the annulus at the bottom of the well when the lead cement gets to the bottom of the liner (when the cement is still inside the pipe)? How many barrels have been pumped when this occurs? (View�!�Fluid Animation Schematic)

13. To reduce the circulating pressures, try using foamed cement. Use a constant flow of gas. Specify the foaming agents to be 2.5% surfactant with no stabilizer. Foam only the cement. Use 9 ppg foam density for all cement and only one segment for each cement stage.

14. Did using foam cement reduce the circulating pressure enough to avoid fracturing the formation?

15. Allow Cementing-Opticem to automatically adjust the cement pump rates in order to avoid the high circulating pressures without using the foamed cement. Use 100 psi safety factor.

a) Does this help?

b) How were the rates adjusted? (View�!�Plot�!�Comparison of Rates In and Out)

c) Does free fall occur?

Answers

1. Using the Well Explorer, double-click on the case name to open it.

2. Click on the Cementing-OptiCem button to select the Cementing application. Select Wellbore Simulator from the Mode drop-down list


WELLPLAN Exercises

3.

4. Use Case > Fluid Editor to define all fluids.

a)

Specify a 15% enlarged hole volume here.

Highlight the 13.35 ppg mud and review the properties.

WELLPLAN Exercises


b)

c)

Enter data for the 12 ppg spacer as specified here.

Enter data for Lead Cement as specified here.


WELLPLAN Exercises

d)

Enter data for Tail Slurry as specified here. Notice that this includes Fann data readings at 95 deg.

WELLPLAN Exercises


Enter data for Tail Slurry as specified here. Notice that this includes Fann data readings at 149 deg. Readings at 185 deg are specified here.


WELLPLAN Exercises

5.

6.

There is a weak zone at 13,253 ft.

WELLPLAN Exercises


a) When the annulus is to be left open to the atmosphere during the entire job, then 14.7 psi [101 kPa] should be entered for the back pressure value and 0 should be used for the return volume.

7.

8.

Do not check this box because we are not taking returns at the sea floor.

Enter the zones of interest.

Yes, the circulating pressures during the cement job exceed the fracture gradient throughout much of the job.


WELLPLAN Exercises

9.

10.

Because the minimum hydrostatic is getting very close to the pore pressure, you should consider the possibility of a kick.

It is likely the weak zone may fracture, because the maximum ECD during the job is greater than the fracture pressure of the weak zone.

Because the rates in and out are equal, freefall does not occur.

WELLPLAN Exercises


11.

12.

The maximum wellhead surface pressure is 2135 psi. It occurs when the displacement fluid begins to be pumped.

About 822 bbls have been pumped when the lead cement gets to the bottom.

When 822 bbls have been pumped, the pressure in the annulus at TVD is about 8194 psi.


WELLPLAN Exercises

13. Be sure to check the Use Foam Schedule box on the Parameter > Job Data dialog. Define foam cement using Parameter > Foam Data.

Click on Lead Cement to specify parameters for that fluid.

Click on Tail Slurry to specify parameters for that fluid.

WELLPLAN Exercises


14. Use View > Plot > Circ Pres and Den - Frac Zone.

15.

Using foamed cement did not reduce the circulating pressure enough to avoid fracturing the formation.

Check box to allow software to automatically adjust the pump rates and to use 100 psi safety factor Do not check the Use Foam Schedule box.


WELLPLAN Exercises

a)

b)

Automatically adjusting the rates does keep the circulating pressure below the fracture gradient.

All of the pump rates were reduced. The rate is 1 bbl/min.

WELLPLAN Exercises


c) Free fall occurs. In the previous plot, the rate out exceeds the rate in therefore free fall is occurring.


WELLPLAN Exercises

Exercise 9: Using Critical Speed Analysis

Steps and Questions

1. Open the Case CSA 12 1/4” BHA.

2. Import the template BHA Critical sp.tpt.

3. Select the Critical Speed Analysis module from the Modules menu, or click the Critical Speed Analysis button. Critical Speed Analysis has only one analysis mode so you don’t need to select an analysis mode.

4. Assume the tri-cone bit has 2000 ft-lbs of torque. The weight on the bit is 20 kips. The Steering Tool Orientation is 0 deg. Analyze the drillstring for every two RPM between 0 and 220. Use an Excitation Frequency Factor of 9 for PDC bits. Check the Dynamics box to include the effects of nodal torque due to friction. (Parameter > Analysis Parameters)

5. Review the Boundary Conditions and Mesh Zone set for the analysis, but don’t change them. (Parameter > Boundary Conditions and Parameter > Mesh Zone)

6. Examine the stresses acting on the workstring.

a) What rotational speeds may result in high relative stress in the workstring? What is the maximum equivalent stress you can expect? (View > Rotational Speed Plots�!�Resultant Stresses)

b) )Where in the workstring are these high stresses likely to occur while rotating at the critical rotational speed? (View > Position Plots�!�Resultant Stresses)

c) What type of stress is causing the high equivalent stress? (View > Position Plots�!�Stress Components)

d) Explain the difference between the View > Position Plots�!�Stress Components plot and the View > Rotational Speed�!�Stress Components plot. (Hint: Split the window and display each plot in a vertical pane.)

WELLPLAN Exercises


e) Using the 3D plots, where is the maximum torsional stress in the workstring, and at what rotational speed is it likely to occur? (View > 3D Plots�!�Stress Components�!�Shear)

7. You have been using an Excitation Frequency Factor of 9 which is typical of a PDC bit. Compare the maximum equivalent stresses using the Excitation Frequency Factor of 9 with the maximum equivalent stresses using an Excitation Frequency Factor of 3. (An Excitation Frequency Factor of 3 is typical of roller cone bits.) Hint: Use Freeze Line and View > Rotational Speed Plots�!�Resultant Stresses)

Answers

1. Use the Well Explorer. Double-click the case you want to open.

2. Use File > Workspace > Open Template.

3. Click on the Critical Speed button to start the Critical Speed application.

4. Use Parameter > Analysis Parameters.


WELLPLAN Exercises

5. Use Parameter > Boundary Conditions to review the analysis boundary conditions.

Use Parameter > Mesh Zone to review the mesh zone.

WELLPLAN Exercises


6. Use the plots (using the View menu) to analyze stresses.

a) Rotating at 132 and 154 rpm may result in high relative stresses. You can not determine from this plot the actual stresses acting on the BHA. This plot displays relative stresses only.

Using the Data Reader, you can determine the relative magnitude of the stress at the largest peak.

The stress at 132 and 154 rpm is several times greater than the stress at the other rpms, however you can not determine the actual stresses acting on the BHA at these rpms.


WELLPLAN Exercises

b) To determine what component is located at a certain position from the bit, refer to Case�!�String Editor.

c)

The high stresses while rotating at 154 rpm are likely to occur in multiple places in the bottom 1100 ft from the bit.

Use the Slider Bar to change the rotational speed.

Axial stress is causing the high relative stress while rotating at 154 rpm.

WELLPLAN Exercises


d)

The View�!�Rotational Speed�!�Stress Components plot displays the stress components for a range of rotational speeds.

The View�!�Position Plots�!�Stress Components plot displays the stress components at one rotational speed.


WELLPLAN Exercises

e) The 3D plots work well for gaining general knowledge of what is occurring. If you need specific details, say for distance from bit, you should use a 2D plot.

The greatest shear stress occurs here.

To rotate the 3D plot, press and hold the left mouse button while moving the mouse. The plot will rotate as you move the mouse.

WELLPLAN Exercises


7. To use Freeze Line, right-click on the curve you want to freeze. “Frozen” lines remain on the plot when the plot is regenerated using new input data.Change the name, color, and the thickness of the line you freeze so that you can identify it.

Relative stress using Excitation Factor of 9. Relative stress using

Excitation Factor of 3.


WELLPLAN Exercises

Exercise 10: Using Bottom Hole Assembly Analysis

Steps and Questions

1. Open the Case BHA 12 1/4” BHA.

2. Activate the Bottom Hole Assembly analysis by clicking the Bottom Hole Assembly button.

3. Ensure the mesh zone is using default values of 20, 100, and 500 for Aspect Ratios 1, 2, and 3 respectively. Set Length 1 to 500 ft and Length 2 to 2500 ft.

4. The current hole inclination is approximately 0 degrees. We are drilling in a soft formation using 2000 ft-lbs bit torque, 20 kips WOB and rotating at 120 rpm. Drillahead 300 ft. Assume a gauge hole. During the drillahead prediction, record wellpath data every 30 ft. Use a Bit Coefficient of 50, Formation Hardness of 30 and ROP of 25 ft/hr. Check the Dynamics box to include the calculation of nodal torque. Will this BHA build angle?

5. Analyze the position of the BHA in the wellbore and the contact forces acting on it.

a) Where is the BHA in contact with the wellbore? (View�!�Plot�!�Displacement)

b) What side force is the BHA subjected to? (View�!�Plot�!�Side Force)

6. Assume the hole is 1/2 inch overgauge. Does this change the build rate?

Answers

1. Use the Well Explorer to open the case by double-clicking on it.

2. Click on the Bottom Hole Assembly Analysis button to select the Bottom Hole Assembly application.

3. Use Parameter > Mesh Zone.

WELLPLAN Exercises


4.

5.

a)

Be sure to check the Enable Drillahead box to predict how the BHA will perform over the Drill Interval specified.

Very slight build.

The BHA contacts the wellbore when the clearance is zero.


WELLPLAN Exercises

b)

6.

An overgauge hole slightly increases the build rate.

WELLPLAN Exercises


Exercise 11: Using Stuck Pipe Analysis

Steps and Questions

1. Open the Case STU 12 1/4” BHA.

2. Select the Stuck Pipe application and Stuck Point Analysis from the Modules menu, or click the Stuck Pipe button and select Stuck Point Analysis from the Mode drop-down list.

3. Setup the analysis parameters (Case > Stuck Pipe Setup Data). The traveling assembly weight is 50 kips. Do not include sheave friction correction. Use 90% of the effective yield to determine maximum overpull. Click OK.

4. Determine the location of the stuck point. Assume you were tripping out when the string became stuck. The initial load of the stretch test was 525 kips and the final load was 600 kips. The stretch was 74 inches. What is the stuck point?

5. Specify the jar operating forces. The up and down set forces are 1 kip. The pump open force is 11 kips, the up trip force is 90 kips and the down trip force is 40 kips.

6. Determine the surface actions to set and trip the jar. The measured weight when stuck is 433 kips. The jars fire downwards and there is no circulation while jarring. What is the measured weight required to trip the jar? What is the measured weight required to reset the jar?

7. Will the loads required to set, trip and reset the jar cause the string to fail?

8. What surface actions are required to backoff at 17,200 ft MD? To backoff, place the stuck point slightly in tension (1 kip) and apply 1,000 ft-lbs of torque.


WELLPLAN Exercises

Answers

1. Using the Well Explorer, double-click on the case to open it.

2. Click on the Stuck Pipe button to select the Stuck Pipe application. Select Stuck Point Analysis from the Mode drop-down list.

3.

4. Use Parameter > Analysis.

5. Use the String Jar Data dialog to specify the jar operating parameters. To access the String Jar Data dialog, double-click on a

The stuck point is at 17,288 ft MD.

WELLPLAN Exercises


non-editable field associated with the jar on the Case > String Editor.

6. Select Jar Analysis from the Mode drop-down list. Use Parameter > Analysis to determine the required surface action to activate the jar.

7. Select Yield Analysis from the Mode drop-down list. Use Parameter > Analysis to determine if the measured weights

The measured weight required to trip the jar.

The measured weight required to reset the jar.


WELLPLAN Exercises

required to set (432 kips), trip (281.2 kips) and reset (322.2 kips) the jars will yield the string.

8. Select Backoff Analysis from the Mode drop-down list. Use Parameter > Analysis to determine the surface actions required.

Although the string buckles, it will not fail using the required measured weights.

WELLPLAN Exercises


Exercise 12: Using Notebook

Steps and Questions

1. Open the Case NBK 12 1/4” BHA, and launch the Notebook module from the toolbar, or using Modules > Notebook. All of the Notebook analysis modes can be selected from the Mode drop down list, and any of the calculations in that Mode can be launched from the Wizard list. Alternatively any of the analysis Modes can be chosen by using Modules > Notebook and the Calculation can be accessed from the Parameter menu. For simplicity, we will use the Mode and Wizard lists for this exercise.

2. Select Hydraulics from the Mode drop down list.

a) Select Pump Output from the Wizard list. Enter the following information for a triplex pump. Stoke = 6.5 in, Vol. Efficiency = 95%, Stroke Rate = 150 spm, and Liner Diameter = 11 inch. Observe the results.

b) Use the Wizard list to select Annular and enter the following general input for Section 1. Flow Rate = 400 gpm, Hole Diameter = 9.625 in, Pipe Diameter = 5 in, and Length = 1000 ft. Although two sections can be calculated simultaneously, enter zeros into the input for Section 2. Observe the results.

c) From the Wizard list, select Pipe, and enter the following data for Section 1. Flow Rate = 400 gpm, Pipe OD = 5 inch, Pipe ID = 4.5 inch, Length = 900 ft. For Section 2 enter: Pipe OD = 7.75 in, Pipe ID = 2.25 in, Length = 100 ft. Observe the results.

d) From the Wizard list, select Nozzle Area. Select the Total Flow Area option and enter the following nozzle sizes to determine the TFA. Use wo 16/32, one 15/32 and one 14/32.

e) Select Fluid Buoyancy from the Wizard list to calculate the buoyancy factor for a given mud weight. Enter a mud weight of 10 ppg. Observe the results.

3. Select Fluids from the Mode drop down list.

a) From the Wizard list, select Mix Fluids to calculate the final volume and density of two combined fluids. Enter: Volume 1 =


WELLPLAN Exercises

400 bbls, Density 1 = 9.7 ppg, Volume 2 = 100 bbls, and Density 2 = 8.33 ppg. Observe the results.

b) Select Dilute/Weight Up Fluid from the Wizard list to calculate the resulting volume when the density of a fluid is increased or decreased. You may opt to keep the Total Volume constant. For this exercise, use: Initial Volume = 3000 bbls, Initial Density = 9.7 ppg, Required Density = 10.5 ppg, and Mix Fluid Density = 12 ppg. Do not check the Maintain Total Volume option. Observe the results.

c) Select Fluid Compressibility from the Wizard list to calculate the volume pumped to overcome the compressibility of the fluid. You can select between WBM and OBM. For this exercise, use: Hole Volume = 1200 bbl, and Test Pressure = 1000 psi. Perform the calculations once for water based mud, and again for oil based mud. It is obvious that OBM is more compressible than the WBM. As a result of the higher compressibility of the OBM, a greater volume of OBM is pumped.

4. Select Miscellaneous from the Mode drop down list.

a) Select Linear Weight from the Wizard list. This options calculates the linear weight in air and the buoyed weight of a section of pipe or casing. Use the following input data: Outer Diameter = 7 in, Inner Diameter = 6.276 in, Length = 3,700 ft, Mud Weight = 9.7 ppg and Steel as the material type. Observe the results.

b) From the Wizard drop down list, select Blockline Cut Off Length to calculate the recommended cut-off length for rotary drilling lines. As the Drum Type, Mast Height, and Drum Diameter are defined, the Cut Off amount is displayed. For this exercise, use Counter Balanced Drum, Mast Height of >161 ft, and Drum Diameter of 36 in. Observe the results.

c) From the Wizard list, select Leak Off Test to determine the formation breakdown pressure, equivalent mud gradient, and formation breakdown gradient based on the leak off test data. Enter the following data: MW = 9.7 ppg, Test Pressure = 1000 psi, TVD = 4,500 ft, Air Gap = 100 ft, and Sea Depth = 300 ft. Observe the results.

5. Select Analysis from the Mode drop-down list.

WELLPLAN Exercises


a) Select Parameter > Workstring > Maximum String Length. Specify a 100 kip Overpull. In a vertical well, how long could the string be before it failed under its own weight?

b) Select Parameter > Workstring > Weight. The current measured depth is 15,000 ft and the mud weight is 15 ppg. What is the buoyed string weight and the weight in air?

c) Select Parameter > Workstring > Elongation. What is the string elongation when 100 kips is applied when the bit is at 15,000 ft in 15 ppg mud?

d) Select Parameter > Volumes/Heights. What is the volume of fluid in the string between 1,000 and 12,000 ft?

e) Select Parameter > Lag Times. How many strokes are required to circulate a sample for depths between 4500 ft and 5,000 ft? Calculate using a 100 ft increment. Click the Pump Equipment button to specify pump details of your choosing.

f) Select Parameter > Spot a Pill. If you want the bottom of a pill to be at 10,000 ft, how much volume do you need to displace?

g) Use Parameter > Block Line Work to calculate the block line work for drilling using data of your choosing.

h) Use Parameter > Rig Capacity to determine the loads applied to the rig while drilling and/or tripping using data of your choosing.

WellPlan Exercie Book

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