1、Recommended Practice for Centralizer Placement and Stop-collar TestingANSI/API RECOMMENDED PRACTICE10D-2FIRST EDITION, AUGUST 2004REAFFIRMED, APRIL 2015ISO 10427-2:2004 (Identical), Petroleum and natural gas industriesEquipment for well cementingPart 2: Centralizer placement and stop-collar testingS
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17、by email to standardsapi.org. The form in this annex is intended for free exchange between owners/operators of the equipment or users of API RP 10D-2. This American National Standard is under the jurisdiction of the API Subcommittee on Well Cements, SC10. This standard is considered identical to the
18、 English version of ISO 10427-2. ISO 10427-2 was prepared by Technical Committee ISO/TC 67 Materials, equipment and offshore structures for petroleum and natural gas industries, SC 3 Drilling and completion fluids, and well cements. API Recommended Practice 10D-2 / ISO 10427-2 ii Contents Page API F
19、oreword . ii Foreword iv Introduction v 1 Scope 1 2 Normative references .1 3 Terms and definitions .1 4 Methods for estimating centralizer placement 3 4.1 General .3 4.2 Standoff ratio calculation .4 4.3 Buoyed weight of casing 5 4.4 Calculations for centralizer spacing .6 5 Procedure for testing s
20、top collars 9 5.1 General .9 5.2 Apparatus 10 5.3 Test procedure 11 5.4 Reporting of test results 11 Annex A (informative) Documentation of stop-collar test results 12 Bibliography .14 API Recommended Practice 10D-2 / ISO 10427-2 iii ISO 10427-2:2004(E) iv ISO 2004 All rights reservedForeword ISO (t
21、he International Organization for Standardization) is a worldwide federation of national standards bodies (ISO member bodies). The work of preparing International Standards is normally carried out through ISO technical committees. Each member body interested in a subject for which a technical commit
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25、 any or all such patent rights. ISO 10427-2 was prepared by Technical Committee ISO/TC 67, Materials, equipment and offshore structures for petroleum, petrochemical and natural gas industries, Subcommittee SC 3, Drilling and completion fluids, and well cements. This first edition of ISO 10427-2, tog
26、ether with ISO 10427-1 and ISO 10427-3, cancels and replaces ISO 10427:1993, which has been technically revised. ISO 10427 consists of the following parts, under the general title Petroleum and natural gas industries Equipment for well cementing: Part 1: Casing bow-spring centralizers Part 2: Centra
27、lizer placement and stop-collar testing Part 3: Performance testing of cementing float equipment API Recommended Practice 10D-2 / ISO 10427-2 iv ISO 10427-2:2004(E) ISO 2004 All rights reserved vIntroduction This part of ISO 10427 is based on API Specification 10D, 5th edition, January 1995 1. In th
28、is part of ISO 10427, where practical, U.S. Customary units are included in brackets for information. API Recommended Practice 10D-2 / ISO 10427-2 v INTERNATIONAL STANDARD ISO 10427-2:2004(E) ISO 2004 All rights reserved 1Petroleum and natural gas industries Equipment for well cementing Part 2: Cent
29、ralizer placement and stop-collar testing 1 Scope This part of ISO 10427 provides calculations for determining centralizer spacing, based on centralizer performance and desired standoff, in deviated and dogleg holes in wells for the petroleum and natural gas industries. It also provides a procedure
30、for testing stop collars and reporting test results. 2 Normative references The following referenced documents are indispensable for the application of this document. For dated references, only the edition cited applies. For undated references, the latest edition of the referenced document (includin
31、g any amendments) applies. ISO 11960, Petroleum and natural gas industries Steel pipes for use as casing or tubing for wells 3 Terms and definitions For the purposes of this document, the following terms and definitions apply: 3.1 annular clearance for perfectly centred casing wellbore diameter minu
32、s casing outside diameter divided by two 3.2 centralizer permanent set change in centralizer bow height after repeated flexing NOTE A bow-spring centralizer is considered to have reached permanent set after being flexed 12 times. 3.3 flexed condition of a bow-spring when a force three times the spec
33、ified minimum restoring force ( 5 %) has been applied to it ISO 10427-1:2001, 3.1 NOTE Specified minimum restoring force values are found in Table 1 of ISO 10427-1:2001. API Recommended Practice 10D-2 / ISO 10427-2 1 ISO 10427-2:2004(E) 2 ISO 2004 All rights reserved3.4 holding device device employe
34、d to fix the stop collar or centralizer to the casing EXAMPLE Set screws, nails, mechanical dogs and epoxy resins. ISO 10427-1:2001, 3.2 3.5 holding force maximum force required to initiate slippage of a stop collar on the casing ISO 10427-1:2001, 3.3 3.6 hole size diameter of the wellbore ISO 10427
35、-1:2001 3.7 limit clamp equivalent term for a stop collar 3.8 restoring force force exerted by a centralizer against the casing to keep it away from the wellbore wall NOTE Restoring-force values can vary based on the installation methods. ISO 10427-1:2001, 3.5 3.9 rigid centralizer centralizer manuf
36、actured with bows, blades or bars that do not flex NOTE Adapted from ISO 10427-1:2001, 3.6. 3.10 running force maximum force required to move a centralizer through a specified wellbore diameter NOTE Running-force values can vary based on the installation methods. ISO 10427-1:2001 3.11 sag point poin
37、t where the casing deflection is at a maximum NOTE Casing that is supported at two points will tend to sag between the support points, this sag is called the casing sag or casing deflection. 3.12 slippage force range range of forces required to continue to move a stop collar after the holding force
38、has been overcome API Recommended Practice 10D-2 / ISO 10427-2 2 ISO 10427-2:2004(E) ISO 2004 All rights reserved 33.13 solid centralizer centralizer manufactured in such a manner as to be a solid device with nonflexible fins or bands NOTE These centralizers have solid bodies and solid blades. 3.14
39、standoff smallest distance between the outside diameter of the casing and the wellbore ISO 10427-1:2001, 3.8 3.15 standoff ratio Rsratio of standoff to annular clearance for perfectly centred casing NOTE 1 It is expressed as a percentage. NOTE 2 Adapted from ISO 10427-1:2001, 3.9. 3.16 starting forc
40、e maximum force required to insert a centralizer into a specified wellbore diameter NOTE Starting-force values can vary based on the installation methods. ISO 10427-1:2001, 3.10 3.17 stop collar device attached to the casing to prevent movement of a casing centralizer NOTE A stop collar can be eithe
41、r an independent piece of equipment or integral with the centralizer. ISO 10427-1:2001, 3.11 4 Methods for estimating centralizer placement 4.1 General The equations presented below are based on certain assumptions and are considered sufficiently accurate for general use. More specific calculations
42、based on complete wellbore data may be available but are beyond the scope of this document. There is no recommendation or requirement for a specific standoff ratio for casing centralization. The standoff ratio of 67 % is used in the specification for the purpose of setting a minimum standard for per
43、formance of casing bow-spring centralizers only. This number is used only in the specifications for bow-spring type centralizers and deals with the minimum force for each size of centralizer at that standoff. The 67 % standoff ratio is not intended to represent the minimum acceptable amount of stand
44、off required to obtain successful centralization of the casing. The user is encouraged to apply the standoff ratio required for specific well conditions based on well requirements and sound engineering judgement. Even a minor change in inclination and/or azimuth, with the string of casing hanging be
45、low it, materially affects the standoff and the requirements for centralizer placement. API Recommended Practice 10D-2 / ISO 10427-2 3 ISO 10427-2:2004(E) 4 ISO 2004 All rights reservedThe lateral load (force) on a centralizer is composed of two components. The first is the weight component of the s
46、ection of pipe supported by the centralizer, and the second is the tension component exerted by the pipe hanging below the centralizer. 4.2 Standoff ratio calculation Annular clearance (la) for perfectly centred casing can be calculated as follows (see Figure 1): wpa2D Dl= (1) where lais the annular
47、 clearance for perfectly centred casing, expressed in metres (inches); Dwis the wellbore diameter, expressed in metres (inches); Dpis the casing outside diameter, expressed in metres (inches). The standoff at the centralizer in a given hole size is represented by the symbol Sc(see Figure 1). The standoff at a bow-spring centralizer is taken from the load deflection curve of the centralizer, tested in that hole size, based upon the lateral load applied (see ISO 10427-1:2001, A.1 2). NOTE Di
