Downhole Testing Services

• Title : Downhole Testing Services by Schlumberger Company
• Publish : Schlumberger 225 Schlumberger Drive Sugar Land, Texas 77478
• Type Document : pdf 
• Release : December 2000
• Total Page : 94 Page
• Size : 3.36 Mb

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Flopetrol Johnston–Schlumberger downhole tools history The history of the drillstem test (DST) goes back to 1926, when E. C. and M. O. Johnston developed the first commercial downhole testing tools. The two brothers were working in the oil fields in Arkansas, USA, where local conditions required frequent and expensive formation testing in a cased hole. The first tool developed incorporated a tester valve and a conical packer element (Fig. 3). It was used in openhole, saving the cost of running casing to test. The field tests were successful, and the brothers continued to work on improving the tools.
Many new tools and techniques were introduced by Johnston Testers. The 1930s saw the introduction of water cushions to reduce differential pressure, a straight hole packer that did not require a core hole and pressure recorders to distinguish between a bad well and tool problems.
During the 1940s reverse circulating subs were invented to get recovered oil out of the pipe before tripping out of the hole. In addition to numerous tool improvements in the 1950s, tubing conveyed-perforating was introduced.

Further developments resulted in the MFE* Multiflow Evaluator system in 1961, the first PCT* Pressure Controlled Tester valve system in 1971, the fullbore PCT system in 1980 and the intelligent IRIS tools in 1992. In 1994 a consortium of 11 clients qualified a full range of tools for hostile HPHT conditions with maximum annulus pressures up to 25,000 psi and temperatures above 400°F [204°C]. Later, a selection of tools with an innovative sealing system was qualified for temperatures up to 500°F [260°C]. The process continues (Fig. 4); the Schlumberger design team liaises with field personnel and clients to develop new downhole tools to further enhance
tthe capabilities of test strings—and thus maintains the tradition started in 1926.

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Deepwater Course Material

• Title : Centrilift 9 Steps ESP Design
• Publish : www.spdltd.com, A member of the Petrofac Group
• Type Document : pdf 
• Release : N/A
• Total Page : 20 Chapter
• Size : 31.19 Mb

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When drilling, it is vital that the actual pore pressure is predicted from the parameters observed.
Available kick tolerance should be constantly updated as the hole section progresses

• If kick tolerance is predicted to fall below the pre-defined acceptable value, consideration must be given to setting casing early 
• for wildcat exploration wells it is advisable to plan the well such that there is a contingency casing string available should this be required

Swabbing can induce an influx in a deepwater well due to

• small margins between pore pressure mud gradient and formation strength 
• high mud gel strength in the upper hole sections where mud temperature may be low 
• consider pumping out of the hole to reduce the risk of swabbing 
• Identify possible requirement to pump out in the drilling programme

When drilling into a potentially abnormally pressured formation in deepwater, it is good practice to make dummy connections or “pumps off tests”routinely

• gas levels at bottoms up must be monitored to check for increased levels of connection gas which could indicate that the hydrostatic static overbalance is close to pore pressure.

A very long riser system can mask gas peaks

• especially if the riser boost line is introducing a significant fraction of the total mud flow at the BOP
• masking effect of the riser is most apparent when drilling smallhole sizes at low flow rates 
• tracking of gas readings may be considerably more difficult in deepwater operations.

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Centrilift Steps ESP Design

• Title : Centrilift 9 Steps ESP Design
• Publish : Centrilift a Baker Hughes Company
• Type Document : pdf 
• Release : N/A
• Total Page : 33 Page
• Size : 7.76 Mb

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The Centrilift Training Center offers high quality education programs, both for centrilift assocoates who design , build and service and for our valued customers.
POur modern training facility includes full media equipped classroms, a shop training area and a media development center. in addition to a permanent staff of proffessional, experienced instructors, numerous memebrs of the centrilift organization are on call in their areas of experience.

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Conventional Surface Wellheads Draft

• Title : Conventional Surface Wellheads Draft by Cameron
• Publish : Western Hemisphere Cameron PO Box 1212 Houston Texas 77251-1212
• Type Document : pdf 
• Release : N/A
• Total Page : 25 Page
• Size : 1.98 Mb

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Cameron Conventional Wellhead Systems provide the flexibility, compatibility and interchangeability required for a wide range of surface applications. With the proven features of Cameron systems comes reduced inventory requirements, lower costs and the ability to provide standard components.
Cameron provides two Conventional Wellhead Systems, the S Wellhead and IC Wellhead. The Cameron S Conventional Wellhead System offers the industry’s highest capacity conventional spool-type wellhead and is designed for use with all well depths and types of completions. The IC Wellhead is a costeffective, reliable system for a variety of applications. Although components are not interchangeable, the S Wellhead may be used in place of the IC Wellhead for all applications. In addition, both wellheads are compatible with most Cameron tubing spool and hanger configurations.
Cameron has earned a reputation for quality wellhead products
that meet or exceed API 6A specifications. Cameron offers a complete line of conventional wellheads and Christmas trees to suit all casing and tubing programs for working pressures up to 30,000 psi. Equipment for surface applications ranges from low pressure, conventional equipment to systems for severe service and geothermal applications. For equipment requirements not covered in this brochure, contact your Cameron representative. Selecting a Wellhead System The first step in determining which Cameron wellhead system is best for your application is to determine the casing hanger style to be used. Each hanger profile is unique and is generally compatible with only a limited number of casing head/spool bowls. Cameron has a complete line of slip-type casing hangers divided into two segments, SB and IC, each serving different applications.

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ESP Handbook

• Title : ESP Handbook
• Publish : N/A
• Type Document : pdf 
• Release : N/A
• Total Page : 67 Page
• Size : 7.78 Mb

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Seals contain a labyrinth chamber with a blacking fluid between the well fluid and motor ail. The blocking fluid is commonly the same ail used In the motor. It may also be a high density fluid for special applications. Seals may also contain a positive elastomeric barrier, or BAG. In combination with a labyrinth chamber. Several operators have Increased run lives using tandem seal sections as an added means of protection.

Gas Separators (optional)

Gas reduces the efficiency of ESPs; therefore. gas separators may be Installed between the seal and pump to reduce the amount of tree gas entering the pump. Both reverse flow and rotary separators are available with the latter being more efficient at gas separation. Some operators run tandem gas separators In high GaR wells 10 more effectively remove gas trom the pump intake. Gas separators handle significant volumes of free gas efficiently.

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Drilling Well Completion

• Title : Drilling Well Completion by Carl Gatlin Departmen of Petroleum The Universuty of Texas
• Publish : Prentice Hall, Inc Englewood Cliffs, NJ
• Type Document : pdf 
• Release : December 2006
• Total Page : 348 Page
• Size : 33.47 Mb

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None

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