半潜平台钻井系统介绍114页PPT
第七章半潜式海洋钻井平台
第七章半潜式海洋钻井平台预览说明:预览图片所展示的格式为文档的源格式展示,下载源文件没有水印,内容可编辑和复制第五章半潜式海洋钻井平台第一节半潜式钻井平台简介一、半潜式平台应用背景辽阔的海洋蕴藏着丰富的资源，其中油气资源的开发是海洋资源开发的重要组成部分。
海洋的平均水深为3730米，其中90%以上海洋面积的水深在200米至6000米之间，74%以上的水深在3000米到6000米间，而目前已探明的海洋石油储量80%以上在水深500米以内，因此有大量的海域面积还有待勘探。
随着世界油气需求的增加，陆上及近海常规水深的开发已趋饱和，海底油气的开采向深水域（水深450-1500米）和超深水域（水深1500米以上）发展。
随着水深的增加，传统的导管架和重力式等平台由于自重和成本的大幅度增大而不适合深水开发，因此适合于深海作业的钻采生产系统成为了研究的热点。
近几十年来，由于墨西哥湾、巴西、西非、北海等深水油气的不断开发，涌现出多种适于深海油气钻采生产的平台型式：张力腿平台（TLP）、Spar、半潜式平台（Semisubmersible）等，其外形及对比如下：半潜式平台又称立柱稳定式平台（Stable Column Platform），是浮式海洋平台的一种常见类型。
半潜式平台由平台主体、立柱（Column）、下体（Submerged Body）或浮箱（Buoyancy Tank）组成，在下体与下体、立柱与立柱、立柱与平台之间通常布置一些支撑连接。
平台上设有钻井机械设备、器材和生活舱室等，供钻井工作用。
平台本体高出水面一定高度，以免波浪的冲击；下体或浮箱提供主要浮力，沉没于水下以减少波浪的干扰力（当波长和平台长度处于某些比值时，立柱和浮体上的波浪作用力能互相抵消,从而使作用在平台上的作用力很小，理论上甚至可以等于零）；平台本体与下体之间连接的立柱，具有小水线面的剖面，使得它具有较大的固有周期，不大可能和波谱的主要成分波发生共振，达到减小运动响应的目的；立柱与立柱之间相隔适当的距离，以保证平台的稳定。
钻井平台系统
CEMENT ADDITIVESThe most important function of oil & gas well primary cementing is to isolate the various zones within the wellbore. In others words, the cement must prevent fluids or gases in one particular zone from mingling with those of another. A properly designed and placed cement slurry accomplishes this by creating the necessary seal between the casing and the formation. The cement must prevent migration or fluid channeling throughout the cement.Today's well cement systems must perform in a variety of down hole conditions, from 0 °C - over 350 °C., and at bottom hole pressures in excess of 30,000 psi. Messina has developed a complete line of cement additives, which modify the characteristics and performance of the cement slurry. This means that a slurry can be designed to function over the wide range of conditions that occur in the wellbore.For more information, please choose from the categories below./Cement/CementAdd-intro.htmlCATEGORIESCementsAccelerators (Code "CA-A")Extenders (CODE: "CA-EX" OR "LWS")Fluid Loss Control Additives (CODE:"CA-FL")Friction Reducers (CODE: "CA-FR")Lost Circulation Materials (CODE: "CA-LC") ANDFormation Control (CODE: "CA-FC")Retarders (CODE: "CA-R")Strength Retrogression Materials (CODE: "CA-HT") ANDWeighting Agents (CODE: "CA-W")Antifoamers (CODE: "CA-AF") AND Foam Cement Additives (CODE: "CA-FA") Thixotropic Cement Additives (CODE: "CA-TX") ANDGas Control Additives (CODE: "CA-GS" OR "LX")Cement Matrix Intensifier (CODE: "CA-SAF"),Lead Slurry Gellants (CODE: "CA-GA"), ANDSalt Cement SlurriesCement Preflushes and SpacersSend mail to messina.oilfield.chemicals@ with questions or comments about this web site.Copyright © 2000 Messina Inc.Last modified: November 08, 2000DIVERTER/bops/blow_out_prevention_Diverter_System.htmDiverters provide the safe venting of shallow gas flows that can be found in some parts of the world. They range from 21 1/4 to 30 inches, with working pressure ranging from 500 to 2,000 psi.Many of today rigs have a diverter housing installed when the rig is built. But it wasn't always this way. For many years much of the diverter equipment in the field was installed before the availability of systems properly designed for diverting. For many years diverting a flow was done using a 21 1/4 Annular rigged up in such away as to open the side ports and close the bag.Diverter malfunctions have led to serous accidents with people and rigs with many blowouts occurring at shallow drilling depths where gas charged sediment A diverter is a safety system that reroutes a well fluid flow away from the rig. Shallow gas is allowed to flow until the well is bridged over or killed by pumping in heavy mud and is intended for use when there is danger of penetrating pressurized shallow gas zone, while the casing shoe strength may not be sufficient to contain shut-in pressures.In some parts of the world the danger of hitting gas as high as 300' to 500' is real threat. In extreme cases the rig may pin down and drill a pilot hole. Modern day diverters are sturdy; resist erosive cut-out, high thrust and impact loads. They are fundamentally simple. Bends that induce turbulence are minimized. Valves, insert cartridges, linkages, and the sequencing process that sometimes cause malfunction are now eliminated. Safeguarding the rig and personnel during the most dangerous phase of drilling. " The Top Hole "Rigs and people were lost due to such flow some form of diverter had to bedeveloped. Many ideas were tried. Many of today diverters are just improvements on what was an idea tried out by men in the field. One of the more successful idea was the use of the annular, a spool with 10 inch outlets and hydraulic valves.Often it would made up and the 21 1/4 annular would diverter. It was designed in such a way that it would fit directly to the 30 inch. This would be accomplished by welding a swage to the larger casing and installing the diverter spool on top and then the annular such a system is still in use to day and can often be found on land rig throughout the world.The concept is simple as the annular closes the sidevents opens. The idea was to make up line from the sp a direct then over the side, often the outlet would be onlya few feet from the water. By making a small manifold tha screwed into the annular the fluid applied to the closin position on the annular would open the vent valves and if applied to the opening po would c ooltgrtlose the side vents.Diverter take an awful beating if put into use. It is there for important that the outlet be big enough to take the flow and debris the formation will push up I would notrecommend side outlets of less than 12 inch and the vent lines as straight as possible. If working offshore I would also recommend the line drops as far and as close to mean sea level as you can possibly get it. This will help keep the line clear by giving a siphoning effect. In the Middle East in the 80's we would use the diverter once running into the major salt water flows. The flows were often accompanied by H2s gas this would be sucked from the floor and dropped 110 feet leaving the floor free of gas.Modem day diverter have many advantages least of all on nipple uptime, a combination of overshot's and riser that fit to the top of thestack make it possible to slide the bell nipple up inside the overshotwith out having to nipple down or move the stack out of the way.Always handy for setting slips or install the next spool or for dumpingcement.With the diverter housing incorporated into the rig sub structure ther is no reason why the bag should not be installed while drilling the main hole sec In area where high salt water flows and shallow gas are known a diverter should always be installed and the bag be used until the protective string of casing iand cemented in plac etion. s run e.boy degasser .As well as install on surface they can be installed subsea. This allows any diverted gas to be taken away from a floating rig by the current. This is normal a bag type diverter with an outlet incorporated and is installed in the riser system.For a diverter to bepermanently installedinto the system,consideration mustbe given to the to theflow path. The flowpath should have atleast 4 directions andthe line a minimum of10 inch, 12 would be better. The flow pathshould have: a lineleading to both side of the rig. One to the flow line for normal circulating and branching from it one to thepoorIt should also have a minimum of 2 operating points with one beside the driller. The second could be in the pusher’s office or in a convenient place outside. The green arrows show the fluid path from the flow line up to the poorboy degasser back down into the flow line. This is done by closing of both diverter "red arrows " closing the flow line "orange arrows " and opening the poorboy line "green arrows ". Many system are rated for 2000 psi. However 30 inch pipe isn't. Of course the bag and housing have a lot more to them but my artistic talent don't stretch that far.The design eliminates line disconnections and reconnections at each installation. The diverter assembly is latched into the permanent housing supported by the rotarybeams. Permanent attachments to the housing include flow line, vent line, overflow line, and hydraulic function connection.tight.The diagram you see are drawings from memory of asystem installed on some of the offshore rigs I have hadthe pleasure of working. It is every efficient circulatingand diverting system.The system had 2 control points One beside the drillerand one in the toolpusher's office. But there was a third.Install on the accumulator unit.Companies such as Cameron and Hydril have continueddeveloped the diverter and the BOP systems to coverevery situation from surface to submerged bottommounted stacks, both have excellent and informativewebsite.There is still a long way to go with this page but drawingstake a long time. However if you have something to add Iwill be more than willing to incorporate it in this page.I really would like someone that has run a subseadiverter or stack to help out as I have no idea what goeson in that area. This had a slight difference. That beingan over ride system that would allow the system to betotally closed in thus enabling stripping operations.As said before modern diverters are solid. There are fewpoints that have to be taken into consideration.• If installed as the riser with the BOPs, the bell nippleflange connecting to the annular must be made up• The overshot pack off must never be closed without pipe inside and the right size overshot must be used.• Always clean and greases the stump for the overshot is to go over.• If drilling out a lot of cement or fast soft drilling take a little time to flush out the diverter lines once a day poetically on top hole "this is where you need it most".• Never ever allow welder to weld around it and drop the rod end on the rotary "Having to pull the inner diverter from the housing with half a ton of old burn of welding rod down the side is a sure way to wreck the block and hook".• Always clean before installing.I know this is standard but having to use the rig skidding system to get them apart.Just a calculation or two:What size is needed for the diverter lines:Lets take 20 in. K55, 106 lbs/ft, ID 19 in. burst pressure of 2410 psi. The pipe on top of the drilling string will be 5 ODThe formula for sizing the overboard line being:SQRT(D2-d2) Ex SQRT(192-52) = SQRT(361-25) = 18.33 in.Often when reading program or calculation you will find only volumes per ft given. I have always been one for working out questions and if I have the answer I like to know the question. If someone give me a volume of .017762 bbl/ft, I would automatically check what is the ID of the pipe. The particular volume here is for a pipe with 4.276 ID but how would you work it out if you did not know:To find out the ID of a pipe from the capacity in bbl/ft. Use the formulaSQRT(volume in bbl/ft x 1029.41) = SQRT(0.017762 x 1029.41) = 4.276 ID.Drilling - Well ControlFor people that are new to this site I must express a word of warning. Although the site has made every effort to bring the subject of well control to the internet it is unfortunately not recognized by any well control school, drilling contractor or oil company worldwide, Therefore I cannot award a certified certificate of merit and the site cannot be used in job application. However it can prepare you for any surface well control certificate and if you should be so lucky as to live in a country that allow the walk in test you would have know problem passing any surface stack test.My advice, if you plan for worst, it won't happen. If it should don't try to being the hero, rig hands are not trained to handle dangerous situation. If things turn bad, get the people to safety and secure the area. Good BOP and emergency drills with the crews are essential. These drills need to be taken seriously and not just as a paper game to make the home office feel good.Testing the casing head and blowout equipment, before and while drilling, will ensure that that if a problem is encountered you are in control. Making a trip and swabbing the well has caused many a fire and blowout. Make sure that all of your flow and volume control devices are working and pay attention to the mud tanks. Make sure all hands have well control school training but more important they understand well control and know their way around the rig.The bottom line is: have the rig supervisors trained to give their people confidence in what they are doing in their 'kick' stations. In short, don't take chances with other people lives, sure, it always happens to the other person? To me, you are the other person.Despite efforts to understand and control formation pressures, blowouts still occur. Nearly every well drilled has the potential to blow out. Experience has shown that blowouts occur as the result of human error or mechanical failures. For a well to Kick certain condition must be met. An imbalance between the formation pressure andthe hydrostatic head of the fluid column at pressured formation. The formation must have sufficient permeability to allow the formation fluids to flow.A blowout is an uncontrolled flow of formation fluids as the result of failure to control subsurface pressures and can occur at the surface or into a subsurface formation. The important of identifying high formation pressures before drilling, detect pressure changes while drilling, and controlling them safely during drilling or workover operations can never be over stressed.The key to effective pressure control is in the preparation and vigilance on the part of those who are responsible for drilling and controlling formation pressures. Training, carefully planning and continuously supervised pressure control program will lessen the possibility of a blowout considerably. Respect for formation pressures and the confidence that comes from training and practice in controlling pressures are the elements that minimize the frequency and severity of blowouts.A second key is understanding: For far to long well control school have approachedthe subject at the end as appose to the beginning. If better understanding of how formation were formed was taken into account people would find that well control problems can be recognized and anticipated before drilling into them. In this writer opinion school tend to concentrate for to much on the cure as appose to prevention.To make it easier to understand a short description will be given of some of the terms used. If some things have to be explained in more detail, there will be a link and a link back.Barrel: a measure of volume for petroleum products in the United States. One barrel is the equivalent of 42 U.S. gallons or 0.15899 cubic meters. One cubic meter equals 6.2897 barrels.Bottom hole pressure: the pressure at the bottom of a borehole. It is caused by the hydrostatic pressure of the well bore fluid, and sometimes any back-pressure held at the surface, as when the well is shut-in with blowout preventer. When mud is being circulated, bottom hole pressure is the hydrostatic pressure plus the remaining circulating pressure required to move the mud up the annulus.Blowout preventer: one of several valves installed at the wellhead to prevent the escape of pressure either in the annular space between the casing and drill pipe or in open hole (i.e. hole with no drill pipe) during drilling and completion operations. Blow-out preventer on land rigs are located beneath the rig at the land’s surface, on jackups or platform rigs, above the water’s surface, and on floating offshore rigs, on the seafloor.Differential pressure: the difference between two fluid pressures; for example, the difference between the pressure in a reservoir and in a well bore drilled in the reservoir, or between atmospheric pressure at sea level and at 10,000 feet. The term shut in means to close in the well to restrict and control the movement of invading formation fluids.Kick means. Formation fluid invading the well bore it can be Water, Oil, Gas or a mixture. Blow Out is the invading fluid has entered the well bore and is out of control. This does not necessarily mean the fluid is at the surface. This could happen under ground and is known as an underground blowout.Hydrostatic pressure: the force exerted by a body of fluid at rest; it increases directly with the density and the depth of the fluid and is expressed in psi or kPa. In drilling, the term refers to the pressure exerted by the drilling fluid in the well bore. In a water-drive field, the term refers to the pressure that may furnish the primary energy for production. This can be found using the formula,(density of fluid * true vertical depth * .052)note: if you are using this site to study, remember this formula it will crop up a lot.Permeability: a measure of the ease with which fluids can flow through a porous rock.Porosity: the ratio of the volume of empty space to the volume of solid rock in a formation, indicating how much fluid a rock holds.Hydrocarbons: organic compounds of hydrogen and carbon, whose densities, boiling points, and freezing points increase as their molecular weights increase. Although composed of only two elements, hydrocarbons exist in a variety of compounds because of the strong affinity of the carbon atom for other atoms and for itself. The smallest molecules of hydrocarbons are gaseous, the largest are solids. Petroleum is a mixture of many different hydrocarbons.Formation Pressure. Formation pressure/Pore pressure are said to be Normal if coursed solely by the hydrostatic head of the subsurface water that is contained in the formation and there is a pore to pore pressure communication with the atmosphere.Normal Formation pressure. is equal to Hydrostatic pressure of water extending from the surface to the subsurface formations. And is derived from the water gradient in that particular area. Gradient of water can be found using the formula,(Weight of water pounds per Gallon* 0.052)The same formula is used for all fluid gradients.Fresh water= 8.33 ppg and is = to1 specific gravity.Note: the degree of the hydrostatic pressure gradient is influenced by the concentration of dissolved solid and gases in the formation fluid. An increasing the dissolved solids increases the formation pressure gradient on the other hand an increase in formation gasses will decrease the formation pressure gradient.The point where atmospheric contact may not be established at sea level or rig level Abnormal Pressures. As we live in the real world, any thing that is not normal is abnormal. Abnormal pressures can be expected in such conditions as:Under compaction in shale’s. More than 50% of the total volume of uncompressed clay could consist of water when first deposited. At this time, it has a high porosity. Under normal conditions, compaction will give a loss of porosity and water. As the overlaying sediments increases the water is forced out and the pore, spaces within the shale are reduced. The result being that water must be removed before any more compaction can continue.If for any reason this balance is disrupted such as, slowing down of the fluid being removal at the proper rate the fluid pressure in the shale will increase. The result a higher porosity for the shale in that area.Pressure: the force that a fluid (liquid or gas) exerts uniformly in all directions within a vessel, pipe, hole in the ground, such as that exerted against the inner wall of a tank or that exerted on the bottom of the well bore by a fluid.Faults: A fault is where the formation slips it could drop or raise as a result you can have some very strange engagements. A brilliant example of this is in the Zit Bay field in Egypt where 2 rigs can be standing along side each other and both be drilling different formations. Pressure trapped in after the formation move can move a high-pressure zone up some 2-3000 feet and trap the pressure inside the fault or it canmove a weak zone down. It is possible that it can do both very close to each other. And if drilling a directional hole can present you with some sleepless night.Tectonic Causes. A horizontal compacting force in the sub formations. Water would normally be released as it is being compacted. However, if another horizontal compacting formation squeezes the clay laterally and the fluids are not allowed to escape as the rate equal to the reduction in pore volume you will get an increase in formation pressure.Salt beds: Salt is one of the main culprits when it comes to over pressured formations. Constant deposit of salt over large areas can cause abnormal pressures. It is totally impermeable when it come to fluid you can encounter many types of saltin the same hole. It behaves plastically. Due to this if can deform and flow acting more like a fluid than solid .as it is heavier than water it will exert it pressure in all direction as the fluid in the formations below can not escape. They will in turn become over pressured.Staying with the salt there is another type that being Diapirism and where salt pushes upward and forms a salt dome disturbing and penetrating the formation above it. This can trap formation fluid due to the folding fault it makes. Much has been said about the mud gradient. How do we test for the formation gradient? (Formation pressure.) A simple test should be run on every new section of the hole. Reservoir: a subsurface, porous, permeable rock body in which oil and or gas is stored. Most reservoir rocks are limestone, dolomites, sandstones, or a combination of these. The 3 basis types of hydrocarbon reservoirs are oil, gas, and condensate. The leak off test: This test is preformed once the casing shoe has been drilled and should be preformed to the point of rupture and not formation brake down. Meaning the pressure applied should show a small loss and not be pumped away into the formation and completely brake down the formation. The test is simple and well proven. The purpose of such a test is to give basic data needed to use in further fracture calculation and to test the cement bond at the shoe.The leak off test is not to be confused with an" Integrity test ". Both have a different roll to play but are similar in approach. The Integrity test is a means of finding out if the casing shoe will take the intended maximum mud weight for the next hole section. This is used in proven fields where the formation pressures are known.The casing shoe is said to be the weakest part of the hole and when a casing string is first drilled out this is true. Once the hole is extended, this test should be run at different intervals. Abnormal pressures change the formation gradient and in some incidents, they will be weaker than at the shoe.As I have said the leak off test, is an information test and from this we get a lot of useful information. Such as The Maximum Allowable Annular Surface Pressure " MAASP" and the Kick Tolerance and the Maximum Allowable Mud Weight All are critical to a safe drilling operation and should be known at all times. They do tend to confuse some people. Therefore, we will spend a bit of time with them. Before we go onto the Well Control side of things.Page of information will be compile and added to the well control section. Hopefullyby the time the section is finished both you and I will all know what I am talking about.I would like to bring up a small point before I continue. Many years ago some very helpful and willing people took both the time and trouble to teach me my trade. As time has passed I too have handed on such information to people that have wantedto learn. This has been done freely and willingly. I intend to complete this well control manual and publish it to the internet in the hope that someone reading it will learnand use it effectively. Since starting I have received quite a few letter from schools. Some have asked what qualifications or right I have to teach. To them and only them let me tell you now so as there will be no more confusion as to who has the right.The manuals you have were written by people that learn there trade long before you started the schools. There is no copyright on well control or it teaching and it is the duty of every experienced hand to teach and train others. Gentlemen you can ether. "Shut up, Put up or what would be a far better idea "JOIN me"" Together we canbuild on the base of what has already been taught and make our industry a safer place to work.Drilling - Blowout Preventer (BOP)When people talk about the blowout preventer they will often refer to it as:a) the Stackb) the BOP'sc) the BOP, all are the same but there are different type.d) the BOPE, this stands for Blowout Preventer EquipmentThe BOP system are a set of valves installed on the wellhead to prevent the escape of pressure either in the annular space between the casing and drill pipe or in open hole (hole with no drill pipe) during drilling, completion and workover operations.Most BOP stacks are designed with a triple ram configuration which provides positive protection against blowouts and secures the well in emergencies. This permits work to be carried out under pressure on surface equipment while the pipe is still in the wellbore. The BOP is placed directly above the wellhead.The BOP closure design consists of a hydraulic actuator assembly connected to each of the two ram assemblies. This allows the rams to be hydraulically compressed around the line from opposite sides which effects a seal thus containing well pressure below the rams.Older bops would need the choke and kill lines on different level or two kill lines so that pressure could be equalized in the event of stripping but now days bops are being designed with this in mind and the pressure across the rams is equalized, through an integral equalizer assembly located between each ram assembly. This takes place prior to hydraulic retraction of the rams and opening of the valve.This system enables the wellbore pressure to be equalized from the bottom to the top of each ram assembly. Ram assemblies may be interchanged to create different configurations. Manual overrides which operate the rams in case of hydraulic failure are also part of the system with handles. These overrides can also hold the rams mechanically locked in the closed position.An innovative attribute on the BOP is the plumbing feature. Single point open n close ports in each modular body permit operation of both hydraulic for each set of rams. BOPs are available in nominal sizes 3 1/16" to 30", with w.p. ratings from 5000 - 20000 PSI. They are useable in both standard n sour environments.Standard ram assembly configurations would normally be as such :1)Pipe seal rams - that serve to seal around the top string isolating the wellbore pressure below the rams2) Shear/seal rams - that serve to shear the tubing and seal off well pressure3)Pipe seal rams - that serve to seal around the top string isolating the wellbore pressure below the rams metal seal adapters, in conjunction with O-rings or rubber are used to make a metal to metal seal on the body to body connection. This configuration results in a highly effective seal at both low and high pressures.The BOPs on land rigs are installed beneath the rig floor just above the surface. On Jack-ups, Swamp barges and platform rigs, they are install below the rig floor but above the mean sea level (MSL) both systems are known as surface stacks . On floating offshore rigs, they will be installed below the mean sea level, on the seafloor or incorporated into the riser. This system is known as a subsea stack .However no matter where they are installed they all provide the same function. To back up or take over should the primary well control fails. The systems collectively are known as the secondary well control system .the n as the "BOP Stack ." The drawing is a Cameron type U single BOP and couldhave a rated Cold w.p. from 2000 - 15000 psi and a boresize of 21 1/4" - 7”. This particular BOP is design forworking on the surface.The U type comes in 2 forms, the single set of ram anda double set. The double is the same with the only difference that there are two rams one on top of the other with no flange connection between them. The bottom of signal will be bolted or clamped to the wellhead. Placed on top will normally be a drilling spool and then the double giving 3 sets of rams. On top will be installed an annular preventer . The combined system is knowA BOP operate from hydraulic pressure that is accumulates in a BOP Accumulator unit that store hydraulic "oil or water" under pressure at 3000 psi. It is then delivered to the BOP having been regulated to an operating pressure of 1500 psi or to the annular at 1000 psi.The operating fluid pushes a set of pistons inside the bonnet into the open and closed position. Attach to the pistons are a set of rams. The ram can be any size depending on the size of the pipe being used. When the rams are closed they are forced around the pipe and seal off the well from below. We refer to this a "shutting in the well"The Annular Preventer is different in as much as it is designed to close arounddifferent sizes of pipe. In this case instead of pushing the seal in and out, it pushes a one piece piston up and down. The rubber insert is pushed up and compressed around the pipe giving an effective seal.This is a Hydrill GK annular Preventer, designed to be wellpressure assisted in maintaining packing unit seal off onceinitial seal off has been effected. As well pressure furtherincreases, closure is maintained by well pressure alone.Exceptions are the GK 7-1/16"-15,000 and 20,000 psiwhich are not well pressure assisted and closing pressuremust be maintained on the BOP to assure seal off. It musthave a minimum closing pressure of 800 psi and isnormally set at 1000 psi operating pressure.。
海上钻井平台各系统简介
钻井平台各系统简介不知道从什么时候起，石油的价格节节攀升。
能源越来越紧张的今天，很多国家把目光从陆地转向了海洋。
自从世界上第一个海洋钻井平台制造出来以后，海洋工程有了长足的发展。
在几十米甚至上3~4000米深的海底钻一口井并不是一件容易的事，因为在海上环境的复杂多变以及恶劣。
经常要承受巨浪和暴风的袭击。
而钻井又要保持一个相对稳定的作业环境。
才能把一根根长长的钻杆钻进海底。
钻井平台从近海到深海，主要可以分为座底式，自升式，半潜式、钻井船等。
座底式是指，平台的结构直接座在海床上，几乎和陆上钻井没多大区别。
所以它们的可钻探深度很有限。
只能在几十米的水深的浅海区域作业。
自升式，又叫jack-up。
顾名思义，这种平台可以象千斤顶一样可以升降它的高度。
它典型的特征就式3-4条腿。
高高的绗架结构。
上面安装又齿条。
平台本体安装有齿轮。
它们一起啮合，传动。
在到达钻井区域的时候，腿就慢慢的伸到海床上。
平台就靠这几条腿站在海里了。
因为考虑到拖航的稳性，腿不能太长。
所以这种平台一般在120~150米水深的近海区作业。
半潜式，最新的已经到了第6代了。
这种平台综合了钻井船和坐底式驳船的优点，是漂浮在海面上的。
这样的话，它们就可以在更深的水域工作了；船体灌放水，可以调节吃水深度，保持船体稳定。
塔的下部是相当容积的浮筒，上面是若干个中空的立柱，支撑着上部平台平台上面是全部的钻井装备和必要的生活设施。
整个平台靠浮筒浮在水面。
它们带有2~3级动态定位系统，海底声纳定位系统，卫星定位系统等来保证平台的相对稳定的坐标。
它们有各种位移补偿装置来补偿海况带来的不稳定状况。
钻井船，钻井船是设有钻井设备，能在水面上钻井和移位的船，也属于移动式(船式)钻井装置。
较早的钻井船是用驳船、矿砂船、油船、供应船等改装的，现在已有专为钻井设计的专用船。
目前，已有半潜、坐底、自升、双体、多体等类型。
钻井船在钻井装置中机动性最好，但钻井性能却比较差。
钻井船与半潜式钻井平台一样，钻井时浮在水面。
半潜式钻井平台
半潜式钻井平台一种海上钻井装置。
上部为工作甲板，下部为两个下船体，用支撑立柱连接。
工作时下船体潜入水中，甲板处于水上安全高度，水线面积小、波浪影响小、稳定性好、自持力强、工作水深大。
半潜式钻井平台，又称立柱稳定式钻井平台，是大部分浮体没于水面下的一种小水线面的移动式钻井平台，是从坐底式钻井平台演变而来的。
半潜式钻井平台,又称“支柱稳定平台”，它是在坐底式钻井平台的基础上发展起来的。
它的结构与坐底式基本相似，下部为一浮筒构架，上部为平台。
它与沉底式不同之处在于：它在工作时不是座在海底，而是像船体一样漂浮在海面上。
当水深较浅时，半潜式平台的沉垫(浮箱)直接坐于海底，这时，将它用作坐底式钻井平台。
当工作水深>30m时，平台漂浮于海水中，相当于钻井浮船。
到目前为止，半潜式钻井平台已经经历了第一代到第六代（可钻3000米）的历程。
它是目前应用最多的浮式钻井装置。
据统计，目前世界上的深水半潜式钻井平台可钻3000多米深，而国内钻井深度一般在300m以内。
半潜式钻井平台主要由上部平台、下浮体(沉垫浮箱)和中部立柱三部分组成。
上部平台任何时候都处在海面以上一定高度。
下部浮体在航行状态下是浮在海面上，浮体的浮力支撑着整个装置的重量。
在钻井作业期间，下部浮体潜入海面以下一定的深度，躲开海面上最强烈的风浪作用，只留部分立柱和上部平台在海面以上。
正是因为在工作期间半潜入海面以下这种特点，被命名为半潜式钻井平台。
这种钻井平台在水深较浅时，也可以坐在海底进行钻井，与坐底式一样。
上部平台半潜式是从坐底式发展而来，所以上部平台部分，与坐底式平台类似，但比坐底式平台要先进得多。
上部平台一般也分成两层，上层为主甲板，下层为机舱。
主甲板上主要放置钻机、井架、钻具、起重设备、消防、救生设备、各种工作间和生活区(一幢楼房)，还有直升飞机平台等。
下层甲板即机舱内主要是机泵组，固井设备，泥浆循环系统，以及各种材料库罐等。
平台的尺度都相当大，所以有很高的自持能力。
深水半潜式平台-讲课
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配置 采用8台柴油发电机组，总功率为40～ 45MW。 8×3,800KW 2台吊机，单台最大起重能力80吨。 ～160人 30天
适于SK-92型直生机起降
二. 深水半潜式钻井平台项目
二. 深水半潜式钻井平台项目
二. 深水半潜式钻井平台项目0米 总宽：约90米 总高：约110米
深海半潜式钻井平台
中国石油大学(华东) 机电工程学院 徐兴平
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一. 半潜式钻井平台的发展
1. 半潜式钻井平台发展现状
☆ 1961年第一条半潜式钻井平台诞生 ☆ 目前已发展到第六代超深水钻井平台 ☆ 在全球现有钻井平台中,半潜式平台约占1/6 ☆ 全球在建钻井平台中,半潜式平台1/3
一. 半潜式钻井平台的发展
吨） 1,000短吨 4×7,500psi，2,200HP泥浆泵 6闸板18-3/4”×15,000psi防喷器组
75至90英尺，立卧结合（75%立放）
二. 深水半潜式钻井平台项目
3. 主要配置（续）
编号
主要性能
10 主动力设备
11 推进器 12 吊机 13 生活区 14 自持能力
15 直升飞机甲板
获得方式
购买旧船 购买旧船 购买旧船 国内研制 购买旧船
作业水深( 米)
304.8 457 457 200 610
建造日 期
1974年 1983年 1982年 1984年 1983年
购入时 间
1979年 1986年 1989年 1994年 1994年
船龄
32 23 24 22 23
建造地点
挪威 挪威 瑞典 中国上海 新加坡
从船体结构上来看，优化了各参数，比以往船型的重量减轻了20～25 ％。
半潜平台钻井系统介绍116页PPT
25、学习是劳动，是充满思想的劳动。——乌申斯基
谢谢！Βιβλιοθήκη 21、要知道对好事的称颂过于夸大，也会招来人们的反感轻蔑和嫉妒。——培根 22、业精于勤，荒于嬉；行成于思，毁于随。——韩愈
1、不要轻言放弃，否则对不起自己。
2、要冒一次险!整个生命就是一场冒险。走得最远的人，常是愿意 去做，并愿意去冒险的人。“稳妥”之船，从未能从岸边走远。-戴尔．卡耐基。
梦 境
3、人生就像一杯没有加糖的咖啡，喝起来是苦涩的，回味起来却有 久久不会退去的余香。
半潜平台钻井系统介绍 4、守业的最好办法就是不断的发展。 5、当爱不能完美，我宁愿选择无悔，不管来生多么美丽，我不愿失 去今生对你的记忆，我不求天长地久的美景，我只要生生世世的轮 回里有你。
半潜钻井平台之推进系统简介
半潜钻井平台之推进系统简介作者：冯永平来源：《中国化工贸易·中旬刊》2018年第06期摘要：随着科学技术发展的日新月异，人类对未知领域的探索范围逐渐增大，大量的深海油气田被发现，可燃冰等新能源被开采利用，这些能源的开采利用极大地促进了深海半潜钻井平台、海上浮式生产储卸油船等一系列高技术深海海洋工程装备的使用。
诸如大功率电力推进系统、半潜钻井平台动力定位等一系列支撑深海作业的新技术被不断地完善升级并投入使用，各种先进的、高端的设备被用于这些海洋工程装备中，例如全回转推进器，对深海海洋工程的发展起到了至关重要的支撑作用。
关键词：推进系统；全回转推进器；组成；功能1 推进系统概述推进系统是半潜钻井平台能够正常作业的一个重要组成部分。
推进系统的主要功能是提供驱动半潜钻井平台运动的推力和力矩，并且对外界的力和力矩起到抵抗的作用。
半潜钻井平台的推进系统主要由原动机和推进器组成。
原动机的作用是将功率提供给推力机构，将功率转化为推力。
原动机一般采用变压器、变频器和电动机。
推进器是将原动机提供的扭矩转换成钻井平台动力定位或者前进动力的装置，其最常用的结构形式是螺旋桨推进器。
螺旋桨推进器包括固定螺距螺旋桨和可调螺距螺旋桨两种。
动力定位系统采用的推进器大致有：主推进器、槽道推进器、全回转推进器、吊舱推进器、喷水推进器等。
半潜钻井平台一般都安装有6套或8套全回转推进器。
2 全回转推进器全回转推进器是一种其推力方向可以相对于随半潜平台坐标系变化的推进器，这种推进器大多是导管式的，固定螺距的，通过伞齿轮系统传动机构使螺旋桨能在水平面内可以绕轴线作360度的回转，可以在任何方向获得最大推力，它可以使半潜钻井平台原地回转、横向移动、急速后退和在微速范围内作操舵等特殊驾驶操作。
安装有多个全回转推进器的半潜平台，其推力分配的优化问题是一个非线性优化问题，在动力定位过程中，各个推进器接收动力定位系统发出的信号命令，改变方向角、输出相应大小的推力，满足动力定位的推力要求。
半潜平台钻井系统介绍
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三、各系统介绍和设备配置
② － ⑩离心泵 各种泥桨离心泵均采用同一品 牌 卧式 机械密封 采用两种规格：125hp， 6×8×14和50hp，3×4×13
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三、各系统介绍和设备配置
袋装切割 机 大袋加料装置
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三、各系统介绍和设备配置
泥桨漏斗
化学泵
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三、各系统介绍和设备配置
三、各系统介绍和设备配置
④ 除泥器
两台除泥器分别层叠在两台振 动筛之上
型号：10T4
20×4”离心筒
处理量：1,500GPM
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三、各系统介绍和设备配置
⑤ 除气器
型号：SWACO CD-1400
离心真空除气器 处理量：1,400GPM
有效节省空间
48
三、各系统介绍和设备配置
1. 井架及附属设备系统 2. 提升系统
9. 高压泥桨系统
10.固井系统
11.试油系统 12.防喷器、隔水管运送系统
3. 旋转系统
4. 泥浆输送系统 5. 固控系统 6. 吹灰系统 7. 司钻控制系统 8. 管子处理机械
13.钻台及附属设备
14.液压动力系统 15.井控系统
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三、各系统介绍和设备配置
derrick drilling system)
7
一、钻井设备介绍和钻井系统设计基础
一个半井架和双井架钻机系统对比
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一、钻井设备介绍和钻井系统设计基础
一个半井架和双井架钻机系统对比 上部设备重量及受风面积减小，对平台稳性更为有利； 相对于双井架钻机系统可变载荷可增加1000吨左右；
减少设备购置费和操作费用；
备用瓶（与隔水管张力器共用） ：8 x 1,600升。
半潜式钻井平台
半潜式钻井平台目录•定义•简介•类型•外型定义具有潜没在水下的浮体（下体或沉箱）并由立柱连接浮体和上部甲板，作业时处于漂浮状态的钻井平台。
简介超深水半潜式钻井平台半潜式钻井平台，又称立柱稳定式钻井平台。
大部分浮体没于水面下的一种小水线面的移动式钻井平台，是从坐底式钻井平台演变而来的。
由平台本体、立柱和下体或浮箱组成。
此外，在下体与下体、立柱与立柱、立柱与平台本体之间还有一些支撑与斜撑连接。
在下体间的连接支撑，一般都设在下体的上方，这样，当平台移位时，可使它位于水线之上，以减小阻力。
平台上设有钻井机械设备、器材和生活舱室等，供钻井工作用。
平台本体高出水面一定高度，以免波浪的冲击。
下体或浮箱提供主要浮力，沉没于水下以减小波浪的扰动力。
平台本体与下体之间连接的立柱，具有小水线面的剖面，主柱与主柱之间相隔适当距离，以保证平台的稳性，所以又有立柱稳定式之称。
半潜式钻井平台的类型有多种，其主要差别在于水下浮体的式样与数目，按下体的式样，大体上可分为沉箱式和下体式两类。
半潜式钻井平台并不像自升式钻井平台那样停留在海床上，反而工作甲板坐落在巨型驳船及中空的支柱上。
钻井平台移动时它们均浮在水面上。
在钻井现场，工人将海水泵入驳船及支柱内以令钻井平台部分浸入水中，亦即其名称半潜式钻井平台所指的意思。
当半潜式钻井平台大部分都浸在水平面下时，它就变成一个用作钻井的稳定平台，只在风吹及水流冲击下稍为移动。
如自升式钻井平台那样，大部分半潜式钻井平台均被拖到钻井现场。
由于它们卓越的稳定性，"半潜式"非常适合在波涛汹涌的海面上进行钻井工作。
半潜式钻井平台可在水深至10000英尺的地方运作。
类型半潜式钻井平台的类型有多种，其主要差别在于水下浮体的式样与数目，按下体的式样，大体上可分为沉箱式和下体式两类。
沉箱式沉箱式是将几根立柱布置在同一个圆周上，每一根立柱下方设一个下体，称为沉箱。
沉箱的剖面有圆形、矩形、靴形。
钻井设备简介课件
contents •钻井设备概述•钻机设备介绍•钻具介绍•钻井泵介绍•辅助设备介绍•钻井设备的发展趋势及展望•钻井设备的应用案例分析目录01陆地钻机主要用于地质勘探、油气开发和地下水开采等领域；而海洋钻机则主要用于海洋油气开发等领域。
此外，根据使用目的和钻探对象，钻井设备还可分为石油钻井设备、地质钻井设备、水文钻井设备等。
根据钻探深度和规模，钻井设备可分为陆地钻机和海洋钻机两大类。
钻井设备的发展历程02钻机的组成01020304钻机主机辅助设备传动系统控制系统井口装置钻头泥浆泵发电机组钻机的主要部件钻机的操作流程准备工作安装钻机调试设备完成作业开始钻井监控数据03稳定器泥浆泵按用途分类可分为整体式钻具、分体式钻具、可调式钻具等。
按结构分类按材质分类确保钻具无损伤、无裂纹、连接部位紧固可靠。
使用前检查操作要求使用过程中监控使用后保养操作人员需经过专业培训，熟悉钻具结构、性能及操作规程。
密切关注钻进状态，发现异常及时停钻检查。
清洗、检查、润滑、存放干燥处。
钻具的使用注意事项04钻井泵的组成01020304钻井泵是一种往复泵，通过柱塞在缸套内作往复运动来吸入和排出流体。
当柱塞向后运动时，缸套内压力降低，流体被吸入；当柱塞向前运动时，缸套内压力增加，流体被排出。
通过多个柱塞的往复运动，可以实现大量流体的吸入和排出。
钻井泵的工作原理钻井泵的分类及特点05作用组成特点030201绞车组成泥浆泵主要由泵头、泵缸、传动轴、吸入管等组成。
作用泥浆泵是钻井设备中的重要组成部分，主要用于向钻头输送高压泥浆，以保持钻头的冷却和清洗。
特点泥浆泵的泵头和泵缸是整个泥浆泵的关键部分，其材料和性能对泥浆泵的使用寿命和效率有重要影响。
泥浆泵组成特点作用顶部驱动装置06高效节能钻井设备智能化技术应用高效节能化自动化钻井技术自动化钻井技术是未来钻井设备的重要发展方向之一。
通过自动化技术，可以实现钻井设备的远程控制、自动化操作等功能，提高钻井作业的效率和安全性。
钻井井控系统简介PPT课件
基本慨况
➢ 常见中深油气井井口防喷器组基本配置由下列几 部分组成： 钻井四通； 双闸板防喷器； 单闸板防喷器； 环形防喷器； 防溢管； 防喷器地面控制装置； 液控管线。
基本慨况
➢ 液压防喷器的最大工作压力与公称通径：
➢ 最大工作压力分为：14Mpa、21Mpa、35Mpa、 70Mpa、105Mpa、140Mpa.
➢ 公称通径分为(括号内为简称)：180mm(18)、 230 mm(23)、280 mm(28)、346 mm(35)、 426 mm(43)、476 mm(48)、528 mm(53)、 540 mm(54)、680 mm(68).
工作原理
➢ 井口防喷器组
➢ 井口防喷器组按工作原理可分为如下三种： 手动关闭/手动打开型； 液压关闭手动锁紧/液压打开型； 液压关闭液压锁紧/液压打开型为例。
➢ 以液压关闭手动锁紧/液压打开型为例： 这是目前应用最为广泛的一种井口防喷器组，它通
过地面控制装置对防喷器进行液动控制，地面控制装置 设置有数个液压油路，可分别或同时控制环形防喷器、 闸板防喷器的一层闸板以及液动平板阀。
➢ ①当双闸板防喷器是两端栽丝时，其组合安装 高度为：7030mm；
➢ ②当双闸板防喷器是上端栽丝下端法兰时，其 组合安装高度为：7360mm。
井口防喷器组安装高度
➢ 常用F35-105防喷器组：
➢ 常规组合：一台FY35-70防溢管(按1.5米高计算)， 一台FH35-70环形防喷器，一台FZ35-105单闸板 防喷器，一台2FZ35-70双闸板防喷器，一台 FS35-105钻井四通。
钻井完整版 ppt课件
钻井完ቤተ መጻሕፍቲ ባይዱ版
• 第一章、钻井地质基础知识 一、岩石的机械性质
1、岩石的机械性质 ⑴岩石的强度：岩石的强度是指抵抗外力破坏的
能力。
⑵硬度：岩石的硬度是指岩石抗压入的极限强
⑶岩石的塑性：在外力作用下，岩石破碎前呈现 永久变形的性质叫岩石的塑性。
⑷岩石的研磨性：钻头破碎岩石的同时，其本身 也受到岩石磨损，这种岩石磨损钻头的能力称 为岩石的研磨性。
⑶在轻钻井液中，固相含量应不超过10％（体积） 或密度不大于1150kg/m3。
⑷无用固相含量与膨润土含量的比值，应控制 在2﹕1～3﹕1。
钻井完整版
• 五）、PH值与钻井工作的影响 • 1、PH值过高，OH-在粘土表面吸附，会
促进泥页岩的水化膨胀和分散，对巩固 井壁、防止缩径和坍塌都不利，往往会 引起井下复杂情况的发生。另外，高PH 值的钻井液具有强腐蚀性，缩短了钻具 及设备的使用寿命。 • 2、通过PH值的变化，可以预测井下情况。 如盐水侵、石膏侵、水泥侵等都会引起 PH值的变化。
⑴粘土岩层。泥岩和页岩一般较软，钻速快，但 容易产生钻头泥包。这种地层极易吸收钻井液 中的自由水而膨胀，导致井径缩小。随着浸泡 时间的延长，井壁会产生垮塌现象，井径扩大。
⑵砂岩层。砂岩一般来说是较好的渗透层，在井 壁上易形成较厚的滤饼，易引起泥饼粘附卡钻。 另外滤饼对测井也有影响，所以必须使用优质 钻井液。
⑶砾岩层。在砾岩层中钻进易发生跳钻、蹩钻和 井壁垮塌。
⑷在当地层软硬交错时，易发生井斜，地层倾角 较大者也易发生井斜。
⑸当岩层中含有可溶性盐类，即钻到石膏层、 盐岩层时，要注意对钻井液性能的影响。
钻井完整版
二、钻井中地质录井工作 1、钻时录井