ANSI API RP 10F-2002 Recommended Practice for Performance Testing of Cementing Float Equipment (Third Edition ERTA September 2003).pdf

《ANSI API RP 10F-2002 Recommended Practice for Performance Testing of Cementing Float Equipment (Third Edition ERTA September 2003).pdf》由会员分享，可在线阅读，更多相关《ANSI API RP 10F-2002 Recommended Practice for Performance Testing of Cementing Float Equipment (Third Edition ERTA September 2003).pdf（25页珍藏版）》请在麦多课文档分享上搜索。

1、Recommended Practice for Performance Testing of Cementing Float EquipmentANSI/API RECOMMENDED PRACTICE10FTHIRD EDITION, APRIL 2002ERRATA, SEPTEMBER 2003REAFFIRMED, APRIL 2015ISO 10427-3:2003 (Identical), Petroleum and natural gas industriesEquipment for well cementingPart 3: Performance testing of c

2、ementing float equipmentAmerican Petroleum Institute API Recommended Practice 10F/ISO 10427-3:2003iSPECIAL NOTESAPI publications necessarily address problems of a general nature. With respect to particularcircumstances, local, state, and federal laws and regulations should be reviewed.API is not und

3、ertaking to meet the duties of employers, manufacturers, or suppliers to warn and properlytrain and equip their employees, and others exposed, concerning health and safety risks andprecautions, nor undertaking their obligations under local, state, or federal laws.Information concerning safety and he

4、alth risks and proper precautions with respect to particular materialsand conditions should be obtained from the employer, the manufacturer or supplier of that material, orthe material safety data sheet.Nothing contained in any API publication is to be construed as granting any right, by implication

5、 orotherwise, for the manufacture, sale, or use of any method, apparatus, or product covered by letterspatent. Neither should anything contained in the publication be construed as insuring anyone againstliability for infringement of letters patent.Generally, API standards are reviewed and revised, r

6、eaffirmed, or withdrawn at least every five years.Sometimes a one-time extension of up to two years will be added to this review cycle. This publicationwill no longer be in effect five years after its publication date as an operative API standard or, where anextension has been granted, upon republic

7、ation. Status of the publication can be ascertained from theAPI Upstream Segment, telephone (202) 682-8000. A catalog of API publications and materials ispublished annually and updated quarterly by API, 1220 L Street, N.W., Washington, D.C. 20005.This document was produced under API standardization

8、procedures that ensure appropriate notificationand participation in the developmental process and is designated as an API standard. Questionsconcerning the interpretation of the content of this standard or comments and questions concerning theprocedures under which this standard was developed should

9、 be directed in writing to the director/generalmanager of the Upstream Segment, American Petroleum Institute, 1220 L Street, N.W., Washington,D.C. 20005. Requests for permission to reproduce or translate all or any part of the material publishedherein should also be addressed to the director.API sta

10、ndards are published to facilitate the broad availability of proven, sound engineering andoperating practices. These standards are not intended to obviate the need for applying soundengineering judgment regarding when and where these standards should be utilized. The formulationand publication of AP

11、I standards is not intended in any way to inhibit anyone from using any otherpractices.Any manufacturer marking equipment or materials in conformance with the marking requirements of anAPI standard is solely responsible for complying with all the applicable requirements of that standard.API does not

12、 represent, warrant, or guarantee that such products do in fact conform to the applicableAPI standard.All rights reserved. No part of this work may be reproduced, stored in a retrieval system, ortransmitted by any means, electronic, mechanical, photocopying, recording, or otherwise,without prior wri

13、tten permission from the publisher. Contact the Publisher,API Publishing Services, 1220 L Street, N.W., Washington, D.C. 20005.Copyright 2002 American Petroleum InstituteAPI Recommended Practice 10F/ISO 10427-3:2003 American Petroleum InstituteiiAPI FOREWORDThis standard is under the jurisdiction of

14、 the API Standards Subcommittee on Well Cements. This APIstandard is identical with the English version of ISO 10427-3:200 31. ISO 10427-3:2003 was preparedby Technical Committee ISO/TC 67, Materials, equipment and offshore structures for petroleum and naturalgas industries, SC 3, Drilling and compl

15、etion fluids, and well cements.For the purposes of this standard, the following editorial changes have been made: Introduction - change 1st sentence to: “This International Standard is based on APIRecommended Practice 10F and supercedes API RP 10F, Second edition, November, 1995.” Clause 4.2 last pa

16、ragraph Replace ISO 13500 with “API Spec 13A” and replace ISO 10414-1with “API RP 13B-1.” Figure 2 - key 6 change “of” to “or.” BibliographyReplace Item 1, ISO 13500 with “API Specification 13A, Drilling Fluid Materials”Replace Item 2, ISO 10414-1 with “API Recommended Practice 13B-1, Standard Proce

17、dure forField Testing Water-Based Drilling Fluids”This standard shall become effective on the date printed on the cover but may be used voluntarily fromthe date of distribution.API publications may be used by anyone desiring to do so. Every effort has been made by the Instituteto assure the accuracy

18、 and reliability of the data contained in them; however, the Institute makes norepresentation, warranty, or guarantee in connection with this publication and hereby expressly disclaimsany liability or responsibility for loss or damage resulting from its use or for the violation of any federal,state,

19、 or municipal regulation with which this publication may conflict.Suggested revisions are invited and should be submitted to the Upstream Segment, API, 1220 L Street,NW, Washington, DC 20005.American Petroleum Institute API Recommended Practice 10F/ISO 10427-3:2003iiiISO ForewordISO (the Internation

20、al Organization for Standardization) is a worldwide federation of national standards bodies (ISOmember bodies). The work of preparing International Standards is normally carried out through ISO technicalcommittees. Each member body interested in a subject for which a technical committee has been est

21、ablished hasthe right to be represented on that committee. International organizations, governmental and non-governmental, inliaison with ISO, also take part in the work. ISO collaborates closely with the International ElectrotechnicalCommission (IEC) on all matters of electrotechnical standardizati

22、on.International Standards are drafted in accordance with the rules given in the ISO/IEC Directives, Part 3.Draft International Standards adopted by the technical committees are circulated to the member bodies for voting.Publication as an International Standard requires approval by at least 75 % of

23、the member bodies casting a vote.Attention is drawn to the possibility that some of the elements of this International Standard may be the subject ofpatent rights. ISO shall not be held responsible for identifying any or all such patent rights.International Standard ISO 10427-3 was prepared by Techn

24、ical Committee ISO/TC 67, Materials, equipment andoffshore structures for petroleum and natural gas industries, Subcommittee SC 3, Drilling and completion fluids,and well cements.Annex A of this International Standard is for information only.API Recommended Practice 10F/ISO 10427-3:2003 American Pet

25、roleum InstituteivIntroductionThis International Standard is based on API Recommended Practice 10F and supercedes API RP 10F, SecondEdition, November, 1995.Users of this International Standard should be aware that further or differing requirements may be needed forindividual applications. This Inter

26、national Standard is not intended to inhibit a vendor from offering, or the purchaserfrom accepting, alternative equipment or engineering solutions for the individual application. This may beparticularly applicable where there is innovative or developing technology. Where an alternative is offered,

27、thevendor should identify any variations from this International Standard and provide details.In this International Standard, where practical, U.S. Customary units are included in brackets for information.American Petroleum Institute API Recommended Practice 10F/ISO 10427-3:2003vContents Page1 Scope

28、 12 Functions of cementing float equipment13 Float equipment performance criteria 23.1 General 23.2 Durability under downhole conditions .23.3 Differential pressure capability from below23.4 Ability to withstand force exerted through cementing plugs from above .23.5 Drillability of the equipment 23.

29、6 Ability to pass lost circulation materials 23.7 Flow coefficient of the valve23.8 Reverse-flow resistance of casing fill-up valves.24 Apparatus and materials.34.1 Flow loop .34.2 Circulating test fluid .44.3 High-temperature/high-pressure test cell.55 Durability test.75.1 Test set-up.75.2 Test cat

30、egories.75.3 Procedure 86 Static high-temperature/high-pressure test86.1 Test categories.86.2 Procedure 97 Test results 9Annex A (informative) Results of performance tests on cementing float equipment .10Bibliography .12API Recommended Practice 10F/ISO 18165:2001 American Petroleum InstituteviAmeric

31、an Petroleum Institute1Petroleum and natural gas industries Performance testing ofcementing float equipment1 ScopeThis International Standard describes testing practices to evaluate the performance of cementing float equipment forthe petroleum and natural gas industries.This International Standard i

32、s applicable to float equipment that will be in contact with water-based fluids used fordrilling and cementing wells. It is not applicable to float equipment performance in non-water-based fluids.2 Functions of cementing float equipmentThe term “cementing float equipment” refers to one or more check

33、 valves incorporated into a well casing string thatprevent fluid flow up the casing while allowing fluid flow down the casing. The primary purpose of cementing floatequipment is to prevent cement that has been placed in the casing/wellbore annulus from flowing up the casing(U-tubing). In some cases,

34、 such as liner cementing, float equipment may be the only practical means of preventingU-tubing. In other cases, the float equipment serves to allow the cement to set in the annulus without having toincrease the pressure inside the casing to prevent U-tubing. Increased pressure in the casing while c

35、ement sets isgenerally undesirable because it can result in gaps (micro-annuli) in the cemented annulus.Float equipment is also sometimes used for the purpose of lessening the load on the drilling rig. Since floatequipment blocks fluid flow up the casing, the buoyant force acting on casing run with

36、float equipment is greater thanthe buoyant force acting on casing run without float equipment. If either the height or the density of the fluid placedinside casing equipped with float equipment while the casing is being run is less than that of the fluid outside thecasing, the suspended weight of th

37、e casing is reduced compared with what it would be without the float equipment.The ability of float equipment to prevent fluid flow up the casing is also important in certain well control situations. Ifthe hydrostatic pressure of the fluid inside the casing becomes less than the pressure of formatio

38、n fluids informations near the bottom of the casing, fluids from the well may try to flow up the casing. In such a situation, thefloat equipment becomes a primary well control device.Float equipment is also sometimes used as a device to assist in pressure-testing of casing. This is normally done byl

39、anding one or more cementing plugs on top of the float equipment assembly. The plugs seal the casing so that thepressure integrity of the casing may be tested.Float equipment is also used by some operators as a device to lessen the free fall of cement inside the casing. Thefree fall of cement is the

40、 tendency of cement to initially fall due to the density differences between the cement and thefluid in the well. The float equipment lessens the free fall, to some extent, by providing a constriction in the flow path.Casing fill-up float equipment is a special type of float equipment that allows th

41、e casing to fill from the bottom as thecasing is run. This is desirable, in some cases, to help reduce pressure surges as the casing is lowered. Fill-up typefloat equipment also helps ensure that the collapse pressure of the casing is not exceeded. Once the casing is run,the check valve mechanism of

42、 fill-up type float equipment is activated. This is normally done by either pumping asurface-released ball through the equipment or by circulating above a certain rate.API Recommended Practice 10F/ISO 10427-3:2003 American Petroleum Institute23 Float equipment performance criteria3.1 GeneralThere ar

43、e a number of performance criteria, listed below, that may be used to evaluate the suitability of a particularpiece of float equipment for a given well.3.2 Durability under downhole conditionsFloat equipment should still function after a fluid containing abrasive solids has been circulated through t

44、heequipment for a period of time. The equipment should function in various orientations and while exposed to elevatedtemperatures and pressures.3.3 Differential pressure capability from belowFloat equipment should be capable of withstanding a differential pressure with the higher pressure being exer

45、tedfrom below the check valve, because the hydrostatic pressure of the fluid occupying the annulus immediately afterthe cement has been placed is usually greater than the hydrostatic pressure of the corresponding column of fluidinside the casing, or while the casing is being run.3.4 Ability to withs

46、tand force exerted through cementing plugs from aboveFloat equipment should be able to withstand a force exerted through cementing plugs from above. Some operatorsoccasionally pressure-test the casing by increasing the pressure shortly after a cementing plug (top plug) used toseparate the cement fro

47、m the displacement fluid has landed downhole. This can cause a force to be applied to thefloat equipment that could cause the equipment to fail.3.5 Drillability of the equipmentFloat equipment should be easy to drill through, since in many cases, float equipment must be drilled out aftercementing.3.

48、6 Ability to pass lost circulation materialsFloat equipment may be required to allow easy passage of lost circulation material (LCM). On occasion, the fluid thatis circulated through cementing float equipment contains LCM designed to bridge on highly permeable, vugular orfractured formations to less

49、en the amount of fluid that is lost to the formations. Since float equipment generallyprovides a constricted flow area for fluid passage, there can be a tendency for the LCM to bridge on the floatequipment valve and partially or totally block fluid circulation. Therefore, the ease with which the LCM can passthrough the float equipment may be a performance criterion for some wells.3.7 Flow coefficient of the valveSince float equipment provides a constriction in the flow path, there will be a pressure loss associated with