'Documents.mx How to Run and Cement Liners Part 1.PDF'

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P a r t 1 H o w t o R u n a n d C e m e n t L i n e r s

1.1

Glenn R. Bowman, Regional Drilling Superintendent, Ashland Ex-ploration, Houston: and Bill Sherer, Operations Manager, Liner

Tools LC and formerly Alexander Oil Tools, Houston

EVEN BEFORE SUCH straightforward procedures as calculatingcement volume or designing liner strings are performed, thedrilling/completion engineer should evaluate well conditions tomake sure all contingencies have been considered. This articlediscusses benets of pipe movement during cementing, but pointsout the impracticality in some cases. When impractical, othermeans can be applied to optimize the job. Also included are currentindustry practices that can cause trouble and the advantages toreciprocating or rotating a liner.

KNOW WHEN TO TAKE A RISK

Effectively cementing liners, (Fig. 1), continues to be a difcult

task in most areas since many operators continue to avoid applyingknown cementing principles, mechanical aids and pipe movement.This becomes more ingrained if the operator has had or heard of a bad experience with a liner. Therefore, most operators haveceased attempting to balance risk with cost efciency in cementingliners. This can result from company policy or fear of failure. Lackof pipe movement, small amounts of cement and expensive rem-edial squeezing therefore are planned for and expected in mostjobs.

The authors do not settle for this low-risk attitude, which inher-ently produces a low degree of success. Instead, we try to applyall known cementing principles and available mechanical techniquesto every liner job, modified as necessary for individual wellconditions. There is not just one company policy for all liners assome operators have adopted. By maximizing the engineering

applied to each well, large economical and technical rewards canbe achieved in an industry characterized by risk.

This article will not describe any new technology in liner ce-menting or equipment, but rather will show how existing methodsare realistically and practically applied. Some case histories andsolutions to problems will also be presented in future articles.

CURRENT INDUSTRY PRACTICES

There probably is nothing more controversial in industry thanhow a liner should be cemented, and many excellent articles havebeen written on this subject.1-22 These articles describe in detailhow liner cementing is performed in certain areas with specicwell conditions. The authors applaud the new boldness in industry

to challenge timid philosophies on cementing liners. As pointedout so aptly by Lindsey.8 Two widely accepted cementing methodsare performed as follows:

x Single stage cement job in which the operator plans tocirculate cement to the top of the liner.

x Planned squeeze program in which the lower part of theliner is cemented and the top of the liner is squeezed later.

Unfortunately, the second procedure is more widely accepted.In addition, the practice of disengaging from the liner hangerbefore cementing is almost universal. According to Lindsey,16

less than 20% of all liner jobs include plans to move the linerduring cementing. There are many reasons for this including:

x It eliminates the risk of being unable to detach fromliner once cement is in place. This can be a serious problecement is brought above the liner top and around the drilland then allowed to set. In some instances, this resultwells being junked, or at the very least, in costly repair. operators consider it an unacceptable risk to stay connectthe liner during cementing.

x It may be necessary to change to a higher strength drill sto enable reciprocation or rotation with drag or torque.

x If centralizers or scratchers are used they may becomtangled with the liner hanger during movement and intewith its use.

x Swab or surge pressures while moving the liner could ceither lost circulation or formation flow if mud weight is to exceeding the fracture gradient or only slightly overbalarespectively.

x Movement of the liner during cementing may knock debrinto the annulus that may form a bridge and cause circulatioplacement problems, or cause the cement to squeeze off iannulus.

x If the liner sticks during movement while cementing, then have to be set in compression. This can cause the liner to b(Fig. 2), which can lead to drill string torque and subsequenton the liner if it is a drilling liner. For a production liner, the ling could make it difcult or impossible to set a packer. Bucproblems can be aggravated even more by higher temperaand pressures during deeper drilling.1, 20, 21, 23

x No liner reciprocation reduces the likelihood that it will be off bottom above a critical pay or lost circulation zone. Anproblem with sticking the liner off bottom is the potential thahole mud and cement may change places (ip op) due to dedifferences once the cement is in place. This could ruin the q

of the cement job around the bottom of the liner.

Figure 1 - An effective cemented liner is one cemented centrically in the hole, with all critical zones isolated fone another and from the liner top and shoe by competent cem

w w w . l i n e r t o o l s . c o mReprinted from World Oil magazine, May 1988 with permission from the authors.

Liner

Hanger

Protective

Casing

Liner

Top

Cement from

the top of the Liner Shoe

O perators trying to minimize risk by refusing to rotate or reciprocate liners while cementing often cost themselves money to repair poor cement jobs. However, practices commonly viewed by some as being risky actually produce better results over the long haul


http://slidepdf.com/reader/full/documentsmx-how-to-run-and-cement-liners-part-1pdf 2/6 w w w . l i n e r t o o l s . c o mReprinted from World Oil magazine, May 1988 with permission from the authors.

x Fear that the drill string may part during reciprocation or twistoff during rotation of the liner is eliminated.

Despite the disadvantages of moving the liner by staying attachedwhile cementing, the authors believe that there are many moreserious economic disadvantages with releasing from the liner beforecementing. They include:

x When hanging off the liner before cementing, seals are disturbedthat isolate the pressures inside the liner hanger setting tool from

pressures on top of the liner, this despite good improvement in sealdesign and packoff bushings. Many liners have had all or part of thecement pumped around the liner setting tool. The same problem canoccur with downhole rotating liner hangers. By staying attachedto the liner while cementing, the problem essentially becomesnon-existent.

x By hanging off rst, the bypass area around the liner becomesa greater restriction, potentially causing lost circulation orbridging in the annulus with cuttings or wallcake, causing suddendehydration of the cement (Fig. 3). Graves has quantified theamount reduced liner hanger areas can also increase equivalentcirculation densities.13

x With downhole rotating liner hangers (the liner is hung off rst,

the setting tool released and rotation initiated), more torque isis required to initiate rotation to overcome bearing friction.16 The liner may become stuck in close tolerance, high differentialpressure, high permeability, or deviated type holes while releasingfrom the liner hanger. By hanging off rst, a circulating restrictionis created that increases the equivalent circulating density. Anotherdisadvantage of these type hangers are that rotation requirementsare controlled by the load on, and consequently, the life of thethe bearings.16, 18 The heavier the liner, the shorter the bearinglife and the slower the liner has to be rotated. Lower rpm meanslower cement-to-mud drag forces. Mechanically set liner hangers(see Fig. 4) are routinely rotated at 40-45 rpm for as long as thejob takes. On one job, a mechanically set liner hanger was rotatedat 120 rpm after the cement turned the shoe. Unquestionably,higher rpm greatly increases the chances for a cement job in any

type of hole. The displacement efciently on this job wasover 92%. There are no bearings to restrict rotation speedtime. Also, with these type hangers, once the liner is on bottthe operator can access hole conditions and then have the opto reciprocate, rotate, or do both. Staying attached can alsothe operator alternate between reciprocation (if torque is high or the rig rotary table goes out) and rotation (if there ismuch drag). Downhole rotating liner hangers do not providthis option.

x The liner running tool stinger cannot be pulled out of the lihanger during cementing as a result of temperature contract

differential pressure or the liner hanger sliding down the hoThis concern becomes more real if high pump rates are desirwhich means higher pump pressures.

x Potential for the annulus packing off with shale and subquent loss of returns is lessened when the operator calternate between rotation and reciprocation.

x Premature shearing of retaining pins holding the liwiper plug is less likely because there is no relative movembetween the liner and setting tool.7

x If cement channels severely and there is a large hydrostadifference between the inside and outside of the running tothe cups or seals can give way before cementing of the linecomplete. In this event, the plug will never be full displacleaving cement to be drilled inside the liner and little orcement around the back of the liner.

As shown above, there are many advantages to working a linby staying attached while cementing. During the two authors’ cbined experience in over 300 jobs, the inability to release the lisetting tool has only occurred twice. One was caused by prematsetting of cement. The other involved mechanical failure during earlier development in the 1960s of the hanger shown in Fig. This has not occurred since the hanger was redesigne

Liner Top

Squeezed

Buckled Interval

Washed Out Hole

Liner

Intermediate

Casing

Uncemented

Interval

Cement Top

from First Stage

Cement Bottom

from Squeeze

Figure 2 - If it is necessary to squeeze the top of a liner, thereis a possibility that there will remain an uncemented interval that

could lead to later pipe buckling (especially if there are majorwashed out sections). For a drilling liner, this could establish wearpoints that may develop into casing leaks. For production liners,the buckling could prevent the proper installation of packers.

Figure 3 - Due to cement’s superior hole cleaning ability (esially if it is in turbulent ow), an accumulation of drilled cuttnot circulated out during drilling could cause a bridge aheathe cement in a narrow annulus. The cement then may suddedehydrate and set prematurely. Some may call it “ash setti

Drill Cutting

Liner

Intermediate

Casing

Liner Hanger (circulating restriction)

Drill Cuttings

from Washout

Cement

Drill String

Cement

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http://slidepdf.com/reader/full/documentsmx-how-to-run-and-cement-liners-part-1pdf 3/6Reprinted from World Oil magazine, May 1988 with permission from the authors. w w w . l i n e r t o o l s . c o m

be achieved, displacing at a maximum owrate was more effive than plug ow displacement.

In the experimental studies cited,25 displacement was not reciably affected by the amount of fluids pumped at low rates. Apparently, once cement determined a ow path, it coued to follow that path with little or no deviation. The chemreaction between cement and mud may have created a coregion that could not be eroded away.

The lab investigation also showed that increasing the dedifference between the uid mud and cement by as much as did not improve overall displacement. The buoyancy force daid in removing the non-circulatable mud because the uidhad lost its mobility had a greater density than the cement,when the uid mud was lighter than the cement. The mud be mobile to let density have an effect.25

The relative importance of the displacement factors mrealized by considering the mud mobility factor defined inpaper25 and the uid velocity of cement. There appeared to bmajor opposing factors in the cement/mud displacement pridentified in the lab investigation, namely: immobility odrilling uid (being resisting force) and ow energy of the dispuid. Displacement was improved by either increasing themobility (the more effective method) or increasing the ow e

Of particular note in the preceding is that plug ow and dedifferences between cement and mud do not affect sefficiency to any degree. Cement should be pumped as fapossible, be it turbulent or laminar ow. Large density differbetween mud and cement aggravate a lost circulation prowhen cementing liners already burdened by close toleraand higher equivalent circulat ing densities. For long linerslow mud weights and high cement densities, keeping the cemeplug ow would entail circulating he well on a choke to slowfall of the cement. Not many operators will be inclined to clate a well on a choke while cementing and then rotatreciprocate the liner with a bag type preventer closed arounwork string.

McLean, Manry and Whitaker,26 showed how impor

pipe movement is - either pipe rotation or reciprocation is benecial to obtaining a primary cement job.

RECIPROCATING AND ROTATING LINERS

Getting the best possible liner cement job in one trthe primary goal of liner movement. Unnecessary, costly tand squeezing can be avoided in numerous instances by aing known cementing and engineering principles with minirisk. The authors view liner cementing as a better opportfor obtaining a primary cement job than in cementing casMany more good cementing practices can be accompliwhile cementing liners than cementing casing. The foreprinciple not being applied is pipe movement, and without itdisadvantage is that effective mud removal from the annu

decreased.

According to McLean, et al.,26 without pipe movement, theno way cement can get between the pipe and hole where thein contact due to casing-hole eccentricity. Bare casing wilagainst the wall of the hole causing the annular cross-sectiocement to be a half-moon instead of a uniform ring. This probecomes more severe in a directional hole in which mud chanare usually adjacent to the casing on the narrow side of theulus. Reciprocation helps because it produces lateral pipe mment that causes the pipe to change sides (lowside to highside, in the wellbore while it is put in compression when slackeand tension when picked up. Rotation helps by pullingcement into wellbore irregularities and displacing the mud ducement-to-mud drag forces (see Fig. 5).

Before describing the design criteria for a liner job, it is neces-sary to rst discuss the advantages of getting an optimum cementjob and how pipe movement weighs heavily in achieving this end.

Figure 4 - Example of a mechanically set rotating

ing or reciprocating liner hanger. The design of the setting tool is such that after cementing, thetool is rotated 18 rounds to the right, which allowsthe slips to be set by slacking off weight with 8 in.of downward movement. In addition, a jaw arrange-ment of the setting tool slips inside the releasingnut so that further rotation releases the liner. Re-ciprocation or rotation can be performed beforereleasing from the hanger while cementing.

GOOD CEMENTING CRITERIAS

Displacement efficiency of cement aroundtubulars when the pipe is not moved dependshighly on the following:24

x Good rheological properties of the drillingfluid.

x Pipe centralization.

x High pump rates.

x The highest possible contact time of ce-ment pumped by critical pumped by criticalintervals.

x The use of cement that exceeds mud density by maximumamount that the conditions will allow.

Another study reconrmed for the most part, the above as goodcementing principles.25 They also concluded the following:

x During test sections simulating realistic downhole permeab-ilities, 100% displacement was never achieved.

x Downhole mobility of the mud system was highly dependent onits thixotropic properties and lter cake disposition characteristicsand this was a major factor in how effectively mud was displaced.

x In a narrow annulus, the slightest decentralization was enough toallow a channel of mud to be bypassed. This was caused by theloss of mud uidity and the resulting nonuniform pressure distribu-tion in the annulus.

x High cement owrates appeared to favorably inuence the muddisplacement process. In lab investigations of mud removal, totaluid ow energy appeared to be more important than turbulentenergy transfer, particularly in a narrow annulus.

xWithin the realistic range of cement and mud rheological proper-ties studied, given in terms of yield point and plastic viscosity, the

rheological differences did not have a measurable effect on thedisplacement process. However, for equivalent ow pressures, acement with a low yield point may be pumped at a higher ow raterate than one with a high yield point. Therefore, when a low yieldpoint cement was used, the displacement process was favorablyinuenced by employing a higher ow rate.

x Throughout the experimental studies, pumping a high yield pointcement at low flowrates was not an effective method of muddisplacement.

x To maximize mud displacement in the lab, cement had to bepumped as fast as possible. Even when turbulent ow could not

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http://slidepdf.com/reader/full/documentsmx-how-to-run-and-cement-liners-part-1pdf 4/6 w w w . l i n e r t o o l s . c o mReprinted from World Oil magazine, May 1988 with permission from the authors.

is always some drag when pulling pipe out of the hole, with thetotal amount of drag indicative of hole condition. Drag shoreduce at a constant rate as pipe is pulled, but if it decreamore in one section it can be anticipated that this sectionsomewhat crooked and may have a keyseat. This section of hin this case would correspond to the hole depth from the topthe drill collars to the bottom of the bit at the point where ddecreased (see Fig 7).

Figure 7 - Keyseats in layered formation. (After Short27)

Keyseats must be avoided while both drilling and runncasing. There are some things that can be done to minimkeyseats. The rst is to minimize sudden changes in hole gle and consequently reduce dog-leg severity. This can be complished by running stiff bottomhole assemblies. A secomethod is to always run spiral rib stabilizers or keyseat wipon top of the top drill collars on bottomhole assemblies. Stalizers and keyseat wipers help “steer” the drill collars out of keyseat “groove” and “wipe” them out. Keyseat wipers shoalso be used if the possibility exists that the drill string mbecome stuck during a trip. Keyseat wipers not only wipe the keyseat and steer the collars away from the keyseat groobut also provide a means of jarring the drill string free ibecomes stuck. Keyseat wipers are available that can jar updown. If the drill string sticks in a keyseat while pulling out hole, then normally the drill string should be jarred down. If drill string becomes stuck in a keyseat while going in the ho

it should be jarred up. On most liner jobs, keyseat problethat occur while pulling out of the hole will not cause a problwith getting a liner in the hole and rotating it, but could caproblems during reciprocation.

If keyseats become severe, another alternative is to rethe section with a drill collar keyseat wiping assembly (Fig. This is a rather drastic procedure and has its risks. Not ois this procedure very hard on drill collar tool joints, a packed hole assembly such as this can be “jammed” inany part ofthe open hole that was drilled with a moexible bottomhole assembly. Because of this, consideratshould be given to reaming all of the open hole down to keyseat section. The best way to avoid this time consum

operation is to drill all the open hole with a stiff bottomh

Figure 5 - Various forces acting to displace, and resist dis-displacement, of by-passed vertical mud column during primarycementing. (After McLean, et al. 26)

Although liner movement should always be the goal, wellconditions may dictate that it should not be tried. For instance,excessive drag may preclude liner reciprocation. If torque is notexcessive, then liner rotation may be planned. If good operationalpractices are followed, however, the authors feel that liner move-ment can be achieved in over 90% of all liner jobs. But certainprecautions need to be followed.

Questions that need to be considered before planning aliner job are as follows: x Is the hole in good condition? x If not, can it be improved economically? x Should plans call for working the liner?

The answer to these questions should be easy to determinebefore a job begins. Drag or torque problems with the drill stringhave already been noted. Drag problems can often, and should be,cleared up before running the liner. A short, small liner (3 ½-in. orsmaller) in a deep well should be hung off rst because it would beimpossible to tell from the weight indicator if it had been releasedor not.

There are two main causes of excessive drag or torque, the rstbeing dog-legs in the well bore that can lead to the formation ofkeyseats (Fig. 6).

Figure 6 - Shaded area shows amount of material that must be removed to wipe out the keyseat completely. (After Short27)

As stated by J.A. “Jim” Short27, “Keyseats can be prevented; theycan be detected; and they can be removed.” The best method ofdetecting keyseats is to observe the weight indicator and drill pipeon trips, especially when pulling pipe out ofhe hole. There

Early

Stage

Middle

Stage

Late

Stage

Drilled

Hole Stages of Keyseat Growth

S o f t F o

r m a t i o n

S o f t

F o r m a t i o n

D r i l l P i p e

H a r d

F o r m a t i o n

H a r d

F o r m a t i o n

S o f t

F o r m a t i o n

S o f t F o r m

a t i o n

Hard Formation

H a r d

F o r m a t i o n

CrossSection

of Drilled

Hole

CrossSection

of DrilledHole

Top of Drill Collar in a Keyseat

Bit in Keyseat

Drill Collar

Bit

Keyseat

Keyseat

H a r d

F o r m a t i o n

Drag force from casing movement (Pos.)

Drag force, mud

on wall (Neg.)

Pressure due to mud column weight (Neg.)

Buoyancy effect of denser cement (Neg.)

Eccentric annulus

Cement slurry

Drag force cement on mud (Pos.)

Differential pressuremoving cement alsoacts on mud (Pos.)

Bypassed mud channel

Casing

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Figure 8 - Examples of drill collar keyseat wiping assemblies(After Short )27

assembly from the beginning. For those who like to drill witha pendulum assembly in soft formations to hold down holedeviation, a packed pendulum can be run (Fig 9). Once TD isreached, the pendulum hookup is moved down to the bit. This meansthat only the length of the pendulum collars will have to be reamed.

Figure 9 - A packed pendulum assembly is used to decrease holehole angle especially when a packed hole assembly is required afterhole angle is reduced. (After Wilson )29

The importance of packed hole assemblies as they apply torunning liners will be discussed later in more detail. Care alsohas to be taken to assure that the well is not sidetracked whilereaming. According to Short,27 the best practice is to ream withthe heaviest weight possible and use high rotary speed. If thereis drag or the hole is taking weight while tripping in the hole,under-reaming may be necessary.

Drag problems or torque problems also can be caused by havinga “dirty” hole. This, along with other variables will be discussedin a future article on getting liners to bottom.

If drag and torque problems occur simultaneously and cannotbe decreased, plans should not be made to move the liner once ithas been run. Instead, once the liner is in place, leave it

there and hang it off immediately in full tension. When an appriateliner hanger is run and if drag is the only problem, thplans could be made to rotate the liner. If torque is a probleplans can be made to reciprocate the liner. This is often tcase in directional wells with high differential pressures and exposands with high permeabilities. A hydraulic hanger should be csidered when severe torque problems are present and cannot remedied.

Ashland does not necessarily attempt to rotate or reciprocadrilling liners since a maximized cement job in this case is onewhich the liner top and the liner shoe do not have to be squeez

with an additional trip of the drill string. This philosophy shochange if large mud weight increases and significantly higtemperatures can be expected during later drilling. Thevariables may increase buckling tendency1,21,23 of tubulars (Figand may dictate the necessity of cementing as much of the linelength as possible. A bad cement job may not provide enoulateral support (especially in large washouts) to keep the lifrom buckling. This becomes more important as drilling time aamount of buckling aggravates casing wear during trips or rotatiIn extreme well conditions, consideration should be givendrilling with oil base mud or an inhibited water base mud to achia closer-to-gauge hole. This will provide more lateral support anslicker hole for liner movement while cementing. Liner bucklwill not be a problem in a close tolerance hole even if there is almno cement behind the liner as long as the hole is in gauge.

Other good cementing criteria beside rotation and recipcation, will be discussed in more detail in future articles

ACKNOWLEDGEMENT

The authors thank their respective managements for permissand encouragement to publish this article and for their progressmanagement philosophy that encourages maximized engineeriefforts on all eld operations. The authors also thank drillforeman Leon Pate and Ray Guidry, and Tim Alexander Jr. sharing their expertise and Judy BenSreti for typing the manuscri

The authors would also like to state that they have readmuch literature and talked to so many people concerning t

subject matter that they realize that the manuscript does ncompletely constitute original thinking. Any credit not givenprevious authors where credit is due is regretted and unintetional.

THE AUTHORS

Glenn R. Bowman is the regional drilling superintendent Ashland Exploration’s Houston Region. He graduated from Maetta College with a BS degree in petroleum engineering and hheld various drilling engineering positions before joining Ashlain 1984. He was most recently drilling manager for Wainoco Oand Gas in Houston. Mr. Bowman is a member of SPE and hauthored several other papers for World Oil on liners and bottohole drilling semblies.

Bill Sherer is the operations manager for Liner Tools LCHouston, and worked for Alexander Oil Tools from 1984-2001 ccentrating on the B&W liner hanger line. Mr. Sherer worked B&W from 1965 to 1979 and later as a consultant for runniliners from 1979 until 1984. Mr. Sherer specializes in optimizat

techniques for cementing liners and has personally supervthe running of over 300 liners.

For more information regarding high rpm liner rotatiocentralization, and primary cementation please contact us or viour website shown below.

Short or High Angle Keyseat

Bi tStabilizers

Long Keyseat

Keyseat

Reamers

Drill Collars

Short or Long

Drill Colar

Stabilizers

Packed Hole

Assemb ly

Pendulum

Vibration

Dampener Dril l Collars

Bi t

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LITERATURE CITED

1 Lindsey, H.E. and Bateman, S.J. “Improve cementing of drilling linersin deep wells.” World Oil. October 1973.

2 Gibbs, Joe. “How to rotate and reciprocate while cementing yourliner.” Drilling-DCW . June 1974.

3 West, E.R. and Lindsey, H.E. “How to run and cement liners in ultra-deep wells.” World Oil. June 1966.

4 Lindsey, H.E. “Running and cementing deep well liners.” World Oil.

November 1974.5 Suman, G.O., and Ellis, R.C. “Cementing Handbook.” World Oil.1977.

6 Lindsey, H.E. “How deep Anadarko wells are designed and equipped.”World Oil. February 1, 1979.

7 Howell, Frank R. “Liner reciprocation while cementing.” Drilling-DCW . July 1979.

8 Lindsey, H.E. “New tools make liner rotation during cementing prac-tical.” World Oil. October 1981.

9 Smith, Dwight K. Cementing Society of Petroleum Engineers of AIMEand Henry L. Doherty Fund of AIME, 1976.

10 Hyatt, C.R. and Partin Jr., M.H. “Liner rotation and proper planningimproves primary cementing success.” SPE 12607, April 1984, Ama-rillo, Texas.

11 Spradlin, Jr., W.N. “Operators tackle Anadarko cementing prob-lems.” Petroleum Engineer International. June 1983.

12 Landrum, W.R. and Turner, R.D. “Rotating liners during cementingin the Grand Isle and West Delta Area.” IADC/SPE 11420. 1983.

13 Graves, Kyle S. “Planning would boost liner cementing success.”Oil and Gas Journal. April 1985.

14 Arceneaux, Mark A. “Liner operations made easy.”PetroleumEngineer International. September 1986.

15 Arceneaux, M.A. and Smith, R.L. “Liner rotation while cementing:An operator’s experience in South Texas.” SPE/IADC 13448. New Orleans,La.

16 Lindsey Jr., H.E. “Rotate liners for a successful cement job.”World Oil. October 1986.

17 Lindsey Jr., H.E. and Durham, K.S. “Field results of liner rotation

during cementing.” SPE Production Engineering. February 1987.

18 Garcia, Juan A. “Rotating liner hanger helps solve cementing problems.” Petroleum Engineer International. September 1985.

19 Reiley, R.H., Black, J.W. Stagg, T.O., and Walters D.A., “Cement ing of liners in horizontal and high-angle wells at Prudhoe Bay, Alaska.” SPE 16682. September 1987. Dallas, Texas.

20 Vangolen, Tracy Smink and Robertson, Wilton G. “Remedial liners repair EOR eld casing damage.” Oil & Gas Journal. Oct. 12, 1987.

21 Durham, Kenneth S. “How to prevent deep well liner failure,”

Parts 1 & 2. World Oil. October and November 1987.

22 Lindsey, H.E. and Durham, K.S. “Field results of liner rotation

during cementing.” SPE 13047, Houston, Texas, Sept. 1984.

23 Goins, W.C., “Better understanding prevents tubular buckling

problems.” World Oil. February 1980.

24 Jones, P.H. and Berdine, D. “Oil well cementing.” Oil & Gas

Journal. March 21, 1940.

25 Haut, Richard C. and Cook, Ronald J. “Primary cement

Optimizing for maximum displacement.” World Oil. 198

26 McLean, R.H., Manry, C.W, and Whitaker, W.W. “Displacem

mechanics in primary cementing.” Journal of Petrole Technology . 1967.

27 Short, J.A. Drilling and casing operations. PennWell Publi

ing Company 1982.

28 Woods, H.B. and Lubinski, A., “Use of stabilizers in control

hole deviation.” Drilling and Production Practices. 1954.

29 Wilson, Gerald E. “How to drill a usable hole.” Parts 1 an

World Oil. September 1976.

Showcase: The Mechanical Rotating Liner Hanger Optimal for medium to long length liners with severe down-hole conditions requiring high burst and collapse.

Applications: Used to run, cement, and rotate a liner at high RPM. Can be drilled into the hole. Optimum for all wells including deviated and S curved wells.

Features: Recessed, tongue and groove slips are pro- tected. Unique design allows rotation and

reciprocation while cementing. High burst and collapse provided by a casing barrel. Resists hostile down-hole environments with optimum material selection. Controlled and evenly timed slips load the casing uniformly, eliminating casing failures due to point loading. Optimum slip angle maximizes the hanging capacity of the liner hanger. Simple to operate, requiring multiple right hand rotations to set the hanger.

Liner Tools LC

Specializing in Liner Primary Cementing

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'Documents.mx How to Run and Cement Liners Part 1.PDF'

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