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Showing posts with label GENERAL DRILLING. Show all posts
Showing posts with label GENERAL DRILLING. Show all posts

Monday, June 3, 2013

WELL CONTROL MANUAL

Foreword

        This manual presents the well control policies and procedures of Transocean SedcoForex. It has been developed with input from Operations, Engineering, Well Construction and Training. This manual is to be kept on all rigs and in the Operations offices and it is to be used as the reference for all well control operations. It is the duty of all personnel involved in well control operations to read this manual to familiarize themselves with the current company policies and ensure that they are followed. This manual must be discussed and reviewed with our customers both offshore and onshore in a timely manner. Any discrepancies or misunderstandings must be clarified before drilling or completion operations begin. Whilst every attempt has been made to capture best industry practices, no manual is perfect and issues you disagree with should be challenged in an appropriate manner. It is your responsibility to keep this a live and healthy document. Well Control is an everyday issue, not just an exam to pass every two years, so for the safety of all concerned please use this manual in your daily business. Above all, THINK about kick prevention and the rest will never have to be used.

Introduction

Transocean SedcoForex personnel can forward recommendations for change to their Region Operations Manager or Regional Training Centre. The proposal for change will be forwarded to the Well Construction Manager who will be responsible for obtaining appropriate approval and preparing the final revision sheet. These revisions will, in turn, be issued to the field.

IMPORTANT NOTICE

Throughout this manual, measurements and formulae have been given in oilfield, metric and SI units. This gives the flexibility for each operation to decide with the client which units are to be used and the appropriate forms made available. THIS DECISION MUST BE MADE AND CLEARLY COMMUNICATED TO ALLCONCERNED PRIOR TO OPERATIONS COMMENCING.

 
Table of Contents
I . Policies & Responsibilities
1.1 Policies
1.2 Crew Responsibilities During Well Control Operations
1.3 Training Requirements
1.4 Exemption Process

II. Well Planning Considerations
2.1 Formation Pressure
2.2 Formation Strength
2.3 Well Planning

III. Well Control Principles
3.1 Primary Well Control
3.2 Secondary Well Control
3.3 Tertiary Well Control

IV. Preparation & Prevention
4.1 Preparation of Equipment and Materials
4.2 Well Control Drills
4.3 Pre-recorded Information
4.4 Kick Prevention During Operations

V. Actions Upon Taking A Kick
5.1 Detecting A Kick
5.2 Containment As Early As Possible
5.3 Shut-in Procedures
5.4 Shut-in Period Prior to Well Kill

VI. Well Kill Techniques
6.1 Wait and Weight Method
6.2 Driller’s Method
6.3 Volumetric Method
6.4 Dynamic Volumetric Method
6.5 Stripping
6.6 Bullheading
6.7 Off-Bottom Kill
6.8 Removing Trapped Gas from the BOP
6.9 Decision Flow Charts
.....








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Thursday, May 30, 2013

OIL AND GAS PRODUCTION HANDBOOK


 
 
PREFACE

This handbook is has been compiled to give readers with an interested in the oil and gas production industry an overview of the main processes and equipment. When I started to search for a suitable introduction to be used for new engineers, I discovered that much of this equipment is described in standards, equipment manuals and project documentation. But little material was found to quickly give the reader an overview of the entire upstream area, while still preserving enough detail to let the engineer get an appreciation of the main characteristics and design issues.,
This book is by no means a comprehensive description on the detailed design of any part of this process, and many details have been omitted in the interest of overview. I have included some comments on the control issues, since that is part of my own background. For the same reason, the description will be somewhat biased toward the offshore installations.
The material has been compiled form various online sources as well as ABB and customer documents. I am thankful to my colleagues in the industry for providing valuable input, in particular Erik Solbu of Norsk Hydro for the Njord process and valuable comments. I have included many photos to give the reader an impression what typical facilities or equipment look like. Non-ABB photo source given below picture other pictures and illustrations are ABB.

 

Edition 1.3 Oslo, June 2006

Håvard Devold

 

©2006 ABB ATPA Oil and Gas
Except as otherwise indicated, all materials, including but not limited to design, text, graphics,
other files, and the selection and arrangement thereof, are the copyright property of ABB, ALL
RIGHTS RESERVED. You may electronically copy and print hard-copy of this document only for
non-commercial personal use, or non-commercial use within the organization that employs you,
provided that the materials are not modified and all copyright or proprietary notices are retained.
Use of photos and graphics and references form other sources in no way promotes or endorses
these products and services and is for illustration only.

 
Introduction

Oil has been used for lighting purposes for many thousand years. In areas where oil is found in shallow reservoirs, seeps of crude oil or gas may naturally develop, and some oil could simply be collected from seepage or tar ponds. Historically, we know of tales of eternal fires where oil and gas seeps would ignite and burn. One example 1000 B.C. is the site where the famous oracle of Delphi would be built, and 500 B.C. Chinese were using natural gas to boil water.
But it was not until 1859 that "Colonel" Edwin Drake drilled the first successful oil well, for the sole purpose of finding oil.
The Drake Well was located in the middle of quiet farm country in north-western Pennsylvania, and began the ternational search for and industrial use of petroleum.
Photo: Drake Well Museum Collection, Titusville, PA
 
These wells were shallow by modern standards, often less than 50 meters, but could give quite large production. In the picture from the Tarr Farm, Oil Creek Valley, the Phillips well on the right was flowing initially at 4000 barrels per day in October 1861, and the Woodford well on the left came in at 1500 barrels per day in July, 5 1862. The oil was collected in the wooden tank in the foreground. Note the many different sized barrels in the background. At this time, barrel size was not yet standardized, which made terms like "Oil is selling at $5 per barrel" very confusing (today a barrel is 159 liters, see units at the back). But even in those days, overproduction was an issue to be avoided. When the “Empire well” was completed in September 1861, it gave 3,000 barrels per day, flooding the market, and the price of oil plummeted to 10 cents a barrel.

Soon, oil had replaced most other fuels for mobile use. The automobile industry developed at the end of the 19th century, and quickly adopted the fuel. Gasoline engines were essential for designing successful aircraft. Ships driven by oil could move up to twice as fast as their coal fired counterparts, a vital military advantage. Gas was burned off or left in the ground.
Despite attempts at gas transportation as far back as 1821, it was not until after the World War II that welding techniques, pipe rolling, and metallurgical advances allowed for the construction of reliable long distance pipelines, resulting in a natural gas industry boom. At the same time the petrochemical industry with its new plastic materials quickly increased production. Even now gas production is gaining market share as LNG provides an economical way of transporting the gas from even the remotest sites.
With oil prices of 50 dollars per barrel or more, even more difficult to access sources become economically interesting. Such sources include tar sands in Venezuela and Canada as well as oil shales. Synthetic diesel (syndiesel) from natural gas and biological sources (biodiesel, ethanol) have also become commercially viable. These sources may eventually more than triple the potential reserves of hydrocabon fuels.





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Saturday, May 25, 2013

FORMULARS AND CALCULATIONS FOR DRILLING, PRODUCTION AND WORK-OVER


CONTENTS
Chapter 1 Basic Formulas

1.      Pressure Gradient

2.      Hydrostatic Pressure

3.      Converting Pressure into Mud Weight

4.      Specific Gravity

5.      Equivalent Circulating Density

6.      Maximum Allowable Mud Weight

7.      Pump Output

8.      Annular Velocity

9.      Capacity Formula

10.   Control Drilling

11.   Buoyancy Factor 12. Hydrostatic Pressure Decrease POOH

12.   Loss of Overbalance Due to Falling Mud Level

13.   Formation Temperature

14.   Hydraulic Horsepower

15.   Drill Pipe/Drill Collar Calculations

16.   Pump Pressure/ Pump Stroke

17.   Relationship

18.   Cost Per Foot

19.   Temperature Conversion Formulas

Chapter 2 Basic Calculations

1.      Volumes and Strokes

2.      Slug Calculations

3.      Accumulator Capacity — Usable Volume Per Bottle

4.      Bulk Density of Cuttings (Using Mud Balance)

5.      Drill String Design (Limitations)

6.      Ton-Mile (TM) Calculations

7.      Cementing Calculations

8.      Weighted Cement Calculations

9.      Calculations for the Number of Sacks of Cement Required

10.   Calculations for the Number of Feet to Be Cemented

11.   Setting a Balanced Cement Plug

12.   Differential Hydrostatic Pressure Between Cement in the Annulus and

13.   Mud Inside the Casing

14.   Hydraulicing Casing

15.   Depth of a Washout

16.   Lost Returns — Loss of Overbalance

17.   Stuck Pipe Calculations

18.   Calculations Required for Spotting Pills

19.   Pressure Required to Break Circulation

Chapter 3 Drilling Fluids

1.      Increase Mud Weight

2.      Dilution

3.      Mixing Fluids of Different Densities

4.      Oil Based Mud Calculations

5.      Solids Analysis

6.      Solids Fractions

7.      Dilution of Mud System

8.      Displacement - Barrels of Water/Slurry Required

9.      Evaluation of Hydrocyclone

10.   Evaluation of Centrifuge

Chapter 4 Pressure Control

1.      Kill Sheets & Related Calculations

2.      Pre-recorded Information

3.      Kick Analysis

4.      Pressure Analysis

5.      Stripping/Snubbing Calculations

6.      Sub-sea Considerations

7.      Work-over Operations

Chapter 5 Engineering Calculations

1.      Bit Nozzle selection - Optimised Hydraulics

2.      Hydraulics Analysis

3.      Critical Annular Velocity & Critical Flow Rate

4.      “D” Exponent

5.      Cuttings Slip Velocity

6.      Surge & Swab Pressures

7.      Equivalent Circulating Density

8.      Fracture Gradient Determination - Surface Application

9.      Fracture Gradient Determination - Sub-sea Application

10.   Directional Drilling Calculations

11.   Miscellaneous Equations & Calculations

CHAPTER ONE
BASIC FORMULAS

1. Pressure Gradient

Pressure gradient, psi/ft, using mud weight, ppg
psi/ft = mud weight, ppg x 0.052                   Example: 12.0 ppg fluid

psi/ft = 12.0 ppg x 0.052
psi/ft = 0.624

Pressure gradient, psi/ft, using mud weight, lb/ft3
psi/ft = mud weight, lb/ft3 x 0.006944           Example: 100 lb/ft3 fluid

psi/ft = 100 lb/ft3 x 0.006944
psi/ft = 0.6944

OR

psi/ft = mud weight, lb/ft3 ÷ 144                    Example: 100 lb/ft3 fluid

psi/ft = 100 lb/ft3 ÷ 144
psi/ft = 0.6944

Pressure gradient, psi/ft, using mud weight, specific gravity (SG)
psi/ft = mud weight, SG x 0.433                    Example: 1.0 SG fluid

psi/ft = 1.0 SG x 0.433
psi/ft = 0.433

Convert pressure gradient, psi/ft, to mud weight, ppg
ppg = pressure gradient, psi/ft ÷ 0.052          Example: 0.4992 psi/ft

ppg = 0.4992 psi/ft : 0.052
ppg = 9.6

Convert pressure gradient, psi/ft, to mud weight, lb/ft3
lb/ft3 = pressure gradient, psi/ft ÷ 0.006944 Example: 0.6944 psi/ft

lb/ft3 = 0.6944 psi/ft ÷ 0.006944
lb/ft3 = 100

Convert pressure gradient, psi/ft, to mud weight, SG
SG = pressure gradient, psi/ft 0.433              Example: 0.433 psi/ft

SG 0.433 psi/ft ÷ 0.433
SG = 1.0

 .....

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Friday, May 10, 2013

INTRODUCTION TO DEEPWATER WELL CONTROL (NEXT - NETWORK OF EXCELLENCE IN TRAINING)

At the end of the lecture, you should be able to: 
  1. Describe the key aspects of well control in deepwater operations
Deepwater well control
  • Define Deepwater Well control? 
  • When can it occur? 
  • Why,how, can it occur? 
  • What are the hazards, risks, probability and consequence of well control incidents? 
  • What plans and processes will be used to manage and control well control incidents? 
  • Are all aspects “fit for purpose” ? 



Deepwater special considerations

  • Preparing to kill a well 
  • Well control with bit off bottom 
  • Well control with bit on bottom 
  • Volumetric stripping operations 
  • Kill with no pipe in hole 
  • Circulating gas from riser and BOP’s 
  • Bullheading operations 
  • Shearing pipe 
  • Shallow well control 
  • Lost circulation


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DEEPWATER EQUIPMENT SYSTEMS (NEXT NETWORK OF EXCELLENCE IN TRAINING)

At the end of the lecture,you will be able to: 
  1. Appreciate the various type of equipment systems used in deepwater operations

Offshore Rig Equipment
  • Work boats 
  • Tubular and riser handling equipment 
  • Compensation equipment 
  • Elevating equipment or Station keeping 
  • Mud system 
  • Subsea equipment 
                  –  Remote operated vehicles (ROV’s)
                  –  Wellheads, templates, manifolds
                  –  Xmas trees BOPs







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