GB2492663A

GB2492663A - Deformed of blocked passage access

Info

Publication number: GB2492663A
Application number: GB1212008.5A
Authority: GB
Inventors: Bruce Arnold Tunget
Original assignee: Individual
Current assignee: Individual
Priority date: 2011-07-05
Filing date: 2012-07-05
Publication date: 2013-01-09
Anticipated expiration: 2032-07-05
Also published as: MX341411B; CN103764940B; BR112014001623B1; EP2729657A4; MX354003B; WO2013006208A2; EP2729657B1; EP2729662A2; WO2013006208A3; GB201212008D0; MX2014000079A; AU2012278973A1; EP2729662B1; GB2492663B; EP2729657A2; CA2841144C; BR112014001623A2; EP2729662A4; AU2012279476B2; AU2012278973B2

Abstract

Method and apparatus of a tool string 8A usable to urge an access passageway through a damaged or blocked well bore. The tool string comprises a deployment string with a lower coiled string compatible connector 17 engaged to at least one circumferentially adaptable apparatus 2A and at least one downhole device deployed in and placed or removed through the well bore to, in use, form a passage. The tool string can be oriented relative to the borehole and comprises a member pivotally connected to the string.

Description

METHOD AND APPARATUS FOR STRING ACCESS OR PASSAGE THROUGH THE

DEFORMED AN11 DISSIMILAR CONTIGUOUS WALLS OF A WELLBORE [0001] The present application claims priority to the United Kingdom patent application having Patent Application Number GBI 111482.4, entitled "Cable Compatible Rig-Less Operatable Annuli Engagable System For Using And Abandoning A Subterranean Well," filed 5 July 2011 and published 4 April 2012 under GB2484166A, United Kingdom patent application having Patent Application Number GB 1111482.4, entitled "Conventional Apparatus Cable Compatible Rig-Less Operable Abandonment Method For Benchrnarldng, Developing, Testing And Improving New Technology," filed 19 September 2011, United Kingdom patent application having Patent Application Number GB1121742.9, entitled "A Space Provision System Using Compression Devices For The Reallocation Of Resources To New Technology, Brownfield And Greenfield Developments," filed 16 December 2011, wherein the description is also published under the related United Kingdom patent application having Patent Application Number GB1121741.l, entitled "Rotary Stick, Slip And Vibration Reduction Drilling Stabilize S With Hydrodynamic Fluid Bearings And Homogenizers," filed 6 December 2011 and published 20 June 2012 under GB2486591, all of which are incorporated herein in their entirety by reference.

[0002] The present invention relates, generally, to well intervention method and apparatus using a tool string comprising any usable downhole device operable with tool string embodiments and a circumferential adaptable apparatus to urge access or passage through a subterranean well bore's dissimilar contiguous passageway walls formed by frictionally obstructive debris thereof; wherein said deformation may have resulted from, for example (e.g.), subterranean strata movements atier well bore installation and/or damage to a well bore from well operations; and whereby lower cost andlor safer pressure controllable coiled string operations usable with the present invention are preferable to higher cost operations comprising, e.g., jointed pipe operations with hydraulic workover units and/or drilling rigs calTying out snubbing and stripping operations or well kill and open bore operations.

[0003] The present invention also relates, generally, to the method and apparatus of forming, piloting and traversing coiled string compatible tool strings through a deformed or restricted well bore passageway's walls or deforming a restricted well bore passageway's walls by, e.g., cleaning, cutting, bending or abrading, substantially differing diameters along a passageway's walls within a well bore during, e.g., well intervention, abandonment, suspension and/or planned side-tracking operations; wherein a proximally contiguous but elTatic well bore axis and/or substantially differing wall circumference along a passageway from. e.g., collapse, damage, scale build-up, hole fill, and/or a completion tailpipe limitations, restrict conventional and prior art access to a lower end of a well bore; and wherein conventional or prior art apparatus downhole devices may be used with the present invention is usable to provide access and passage to said lower end well bore.

FIELD

[0004] The present invention relates, generally, to method and apparatus for providing access to a lower end wellbore through an impasse using various conventional downhole devices to pilot or enlarge an existing frictional or restricted passageway with dissimilar well bore walls, wherein piloting a tool string may comprise displacing debris within and/or deforming its proximally circular and/or deformed bores, and whereby various prior art downhole devices may be deployed and oriented relative to a proximal axis or proximally contiguous wall using the expandable and collapsible members of the present invention engaged about a plurality of shafts usable to pilot the tool stnng through said impasse or restriction using, e.g., sliding, bending or vibration of a dowithole device to circumvent restraining friction or restrictions an traverse around said impasse or use various explosive, hydraulic, electric or rotary forces to cut or wedge dissimilar contiguous passageway walls.

[0005] Tool strings of the present invention may use the interoperability between coiled string conveyable tools for pilotable access or forcible defoimation of substantially differing circumferences along a wcll bore's axis or continuous but changing axis, wherein the tool string may controllably use substantial hydraulic and explosive forces to. e.g., compress, crush, press, impact, cut, perforate, shear, enlarge or otherwise displace an intervening frictional or restrictive wall of a well to provide passage from one passageway to a substantially differing continuation or axially differing subterranean passageway to provide access or passage a lower passageway of a well bore.

[00061 The present invention may be used with any deployment string, whereby a coiled string is preferable to provide the significant benefit, over prior art, of being applicable to a significantly larger population of wells, typically with lower costs with lower well control risks due to the greater pressure control provided by a grease head or stuffing box seal around coiled strings during deployment, whereby the existing above surface well ban-icr pressure containment envelope may be left in place.

[0007] The present invention further provides benefit over prior art by providing method and apparatus for well intervention where none has previously existed. The cited references, typical of pnor art, generally pertain to wireline and coiled string deployment using the limited force of conventional tools unable to orient explosive devices axially because said prior art may be, e.g., propelled out of the well or otherwise damaged or stuck within the wellbore if operated with the same hydraulic andlor explosive forces usable with the present invention. The present invention provides additional benefit by teaching friction reducing methods and apparatus conventionally usable with coiled tubing and drill strings, but unavailable to wireline. To the extent possible, since applicable conventional practice and prior art does not exist for the problems solved herein, said practice arid prior art may be described by: US 2,618,345 A 7/1948 Tucker 166/19 US 2,76i,384 A 2/1951 Sweetman i02121.8 US 2,942,666 A 12/1956 True, et. al. 166/135 US 3,187,813 A 12/1961 Greene 166/55.1 US 3,481,402 A 1/1968 Beckett 166/290 US 3,282,347 A 3/1965 Chenoweth 166-196 US 3,891,034 A 1/1974 Owen and Terrell 166/285 US 3,872,925 A 3/1974 Owen, et. al. 166/286 US 4,349,071 A 11/1980 Fish 166/124 US 4,350,204 A 6/1980 Horton 166/175 US 4,554,973 A 11/1985 Shonrock, et. al. 166/192 US 4,696.343 A 5/1986 Anderson et. a!. 166/164 US 4.671.356 A 6/1987 Barker, et. al. 166/285 US 5,228.519 A 11/1991 Coronado. et.al. 166/387 US 5.154.230 A 12/1991 Dees 166/277 US 5,392.856 A 10/1993 Broussard 166/285 US 6.279,670 BI 5/1997 Eddison, et. al. 175/107 US 6.050,336 A 10/1997 Willauer et.al. 166/286 US 6,076,601 A 6/1998 Mooney 166/297 US 6,341,654 B! 4/1999 Wilson. et. al. 166/387 US 6,454,001 BI 12/2000 Thompson, et. al. 166/250.14 US 6.805.056 BI 4/2003 Poe 102/307 US 6,896,049 B2 1/2003 Moyes 166/82.1 US 7,172,028 B2 3/2003 Barbee, et. al. 166/383 US2007/0107913 Al 11/2006 Arnold, et. al. 166/387 US 7,591.318 B2 7/2006 Tilghrnan 166/376 US 7.681.651 B2 3/2007 Loughlin 166/387 US2008/0230235 Al 3/2007 Loughlin 166/387 US 7,617,880 B2 10/2007 Loughlin 166/387 US 7,878,247 B2 1/2009 Missdbrook. et. al. 166/298 US 7,905,291 B2 11/2007 Kotsonis, et. al. 166/311 US 8,167,051 B2 7/2007 Eddison, et. at 166/381 US 2008/0217019 Al 3/2008 Walker, et. al. 166/312 US 8,166,882 B2 6/2009 Yang 102/476 US 8,109,331 B2 4/2009 Lynde, et. al. 166/105.3 US 2010/0032154 Al 8/2008 Gillan 166/174 GB2483675 A 9/2009 Tunget E2IB GB2471760 A 7/2010 Tunget E2IB U52010/0276204 Al 11/2010 Connell, et. al. 175/293 U5201 1/0168447 Al 12/2010 Scott, et. al., 175/57 US2OII/0240058 Al 10/2010 Jonassen 134/8 Other pubHcations: TAM International, "TAM Inflatable Packer Element Selection," Nov, 2010; and TAM International, "Thru-tubing Workover Services Run On: Drill Pipe, Tubing, Coiled Tubing, Electric Line, Slickline," Jul. 2008.

[0008] Prior art US 2618345 teaches a wireline conveyable expandable axial pivotal spring slips usable with a conical packer engagement to a wall of a well bore that might, for those who do not practice the art, appear similar to various embodiments of the present invention, however it is neither taught nor is it obvious how the devices of US 2618345 could be fashioned to be moveable or achieve the expanded diameter to collapsed diameter ratio necessary for passage through, e.g., a collapsed conduit bore's walls. Similarly, US 2942666 teaches an expandable membrane with axial pivotal slips for securing a bridge plug or packer within a well, wherein the expanded diameter to collapsed diameter is greater, and whereby the tool may be deployed through significantly smaller diameters, then enlarged and engaged to the well bore wall; however, like US 2618345, US 2942666 is intended to be fixed to a bore and not piloted and traversed through dissimilar contiguous well bore walls.

Prior art US 2761384 teaches the use of explosives to cut a conduit downhole, but.

as is common to such applications, cutting of the conduit occurs transverse to the conduit's axis. Accordingly, if the visual similarity of deployment or fixing of such downhole devices through or to a weilbore wall, or explosively cutting conduits downhole, was obvious, disclosure of US 2618345, US 2761384 and US 2942666 filed in 1948, 1951 and 1956 would have rendered the majority of the remaining cited references obvious.

[0009] Similarly, the present invention method and apparatus embodiments for providing access or passage through a dissimilar contiguous passageway could not obvious to those who practice the art, since said practioners have ask the present inventor for a solution.

[00010] Prior art US 3187813 relates to the wireline dumping of cement upon, for example, a restriction or bridge plug provided by the teachings of US 3282347, US 3481402, US3891034, US3872925, US4349071, US4554973, US4671356, US4696343, US 5228519, US 6050336, US 6341654, US 6454001, US 7617880, US 7681651, US 2007/0107913 and US 2008/0230235, reciting various baskets, bridge plugs and/or bladders and expandable or axial pivotal wall securing engagements that are visually similar to US 2618345 and US 2942666, but silent to the passage of a downhole device past a restriction. Such prior art may also include the deformable members taught in US 6896049, which is used in a downhole device, and which is silent to the potential deformity of well conduits and piloting of such devices into, e.g., a damaged or debris filled well bore.

[00011] The majority of prior art presumes a circular well bore without significant restriction to deployment of a downhole device; for example, US 4696343 and US 6454001 are usable for passage of an axial pivotal collapsed and expandable wireline operable umbrella or basket deployable through a casing into a substantially different uncased open strata hole for engagement with the wall of a well, but are silent to deployment through, for example, a collapsed casing.

[0010] Prior art teaches various setting tools, such as US 5392856 and US 7172028, for baskets, umbrellas and bailers usable in, e.g., a wellbore plug back operation, wherein prior art setting tools may include various triggers, timers, springs, battery packs and/or releasable differential pressure vessels usable for the necessary energy to actuate downhole devices.

[0011] Prior art is also. generally, silent to practicable cost effective means of depthying or urging a downhole device's deployment through, for example. the debris of a collapsed casing section. Despite teaching debris management, US 8109331 is sflent to the debris of well component failures like casing or tubing collapse and, generally, cannot be oriented axially downward to either cut or expand a failed well conduit.

Similarly, US 5 154230 teaches the repair of a liner and the explosive shape charges of US8166882 may be used to cut, for example, a failed and/or collapsed well conduit traverse to a well conduit axis, while US 6076601. US 6805056 and US 75913] 8 provide a method and apparatus usable for explosively cutting, and wherein US 75913 18's cutting of a downhole plug and pushing it downhole, and whereby US 7591318's numerous cited references teach various means of deforming a downhole well bore; however prior art does not teach a practicable means of piloting and orienting "axial" cutting tools downward to sculpt through andlor expand, e.g., the collapsed portion of a deformed liner, and whereby the downward orientation of such prior art would result in launching said prior art upward within the well bore, in a similar to a bullet being shot from the barrel of a rifle.

O012] GB2486591 of the present inventor teaches stator rotation within rotary milling tools using a hydrodynamic fluid bearing alTangement, while prior art US 2011/0168447 teaches a means for passage of a casing through the proximally circular or deformed circumference of a well bore filled with, for example, cuttings from boring, whereby turbine blades are used about the circumference of the downhole device to move debris with a reamer shoe for placement of casing, but the application is silent regarding cable or wireline compatible deployment of a downhole apparatus, and wherein the use of fluid to operate such a turbine from a cable engagement is far from obvious.

[0013] Prior art US 2008/0217019, US 7878247, US 7905291B2, US 4350204, US 2010/0032 154 and US 20 11/0240058 teach various coiled string compatible methods and apparatus for access or passage through a well bore filled with, e.g., cuttings or scale in vertical and hoiizontal wells, albeit said access and passage comprises the removal of the debris through circulation as a tool string is deployed into a wellbore, wherein the obstruction is always below or in front of the tools string, and whereby said prior art is silent to the interoperability between tools in the deployment string necessary to pilot a tool string and traverse through intermediate debris andior damage to a lower end of a well bore without the removal of said debris through the act of well bore circulation.

[0014] While various conventional and prior art may be arranged and deployed using the present invention's method and/or piloted by the present invention's apparatus; however, it is not obvious to industry how said conventional or prior art may be practicably deployed to repeated access and provide passage to a wells lower end by piloting and seledive orientation of a tool string relative to substantially differing circumferences along an erratic axis of a contiguous passageway's walls; formed by deformation or damage along and/or debris within or on the dissimilar passageway walls, which is taught herein.

BACKGROUND

[0015] Some of the problems solved by the present invention were presented to the inventor by a major oil and gas producer; who had queried the practicing service companies of the industiy and found they were unable to provide a suitable solution. In particular, the producer had numerous wells with the same problems, described by Figures 7 to 10, 14 to 16, and 20, wherein well conduits of significant wall thickness, metal grade and hardness had been collapsed and/or sheared by moving subterranean strata above a carbonate reservoir being driven by a water flood, and whereby the conventional use of milling operations was unsatisfactoiy for various reasons, including inadvertent side-tracking of wells which would result in a complete loss of access to a producing reservoir, whereby a lack of cementation behind various casing strings resulted from difficulties during well construction caused by trying to pass said movable strata formations, which could result in leak paths and associated reservoir pressure control issues during conventional milling and/or after abandonment of the well's lower end. Accordingly, after having surveyed the industry, said producer determined that solutions to these problems were neither available nor obvious.

[0016] Having been question by the producer with no obvious solutions available for the customer, a major service provider seeking to work with said producer also asked the present inventor how the published application GB2484166A of the present inventor might be used and/or adapted to meet the needs of said major producer.

[0017] Having the problem defined, the present invention's method and apparatus were adapted to be compatible with the method and apparatus of GB2484166A, wherein the safe abandonment of damaged well bores and/or well bores with oval shaped casing circumferences that reduce the effectiveness of, e.g., piston packers for crushing of well components to form a geologic sealable space, was one of the various objectives of the present invention.

[0018] Typically, subtelTanean wells target and exploit subtelTanean deposits of hydrocarbons, geothermal heat sinks, salt layers or other subterranean features that, generally, have been formed by natural stratigraphic traps and subterranean movements of strata within the earth's crust that have trapped and formed the desired deposit.

[0019] While said strata movements may have trapped the deposits over a geologic time frame, the using or exploiting of a subterranean deposit can change the subtelTanean pressures and/or the original in place rock stresses formed before exploitation of the deposit, wherein pressures within strata pore spaces and/or connecting fault planes about a well bore may be increased by injection (e.g. from a water flood) or depleted (e.g. by production) and, thus, promote or attract fluid pressure and/or strata movements dependent upon the abihty to transmit pressure, that can cause subterranean strata to shift over the life of a well. For example, if an impermeable layer of strata separates a higher pressure porous and/or permeable layer from a lower pressure porous and/or permeable layer the higher pressure may act upon the impermeable strata and form a very large piston with substantial associated forces comprising the pressure differential multiplied by the area affected by the pressure difference, which will typically be measured in square miles or kilometers. When a reservoir pressure is depleted and pressures above the reservoir cannot equalize with the depleted reservoir strata, movement typically referred to as subsidence may occur. The injection of water using, e.g., a water flood may tend to equalize pressures or provide insufficient pressure support and/or, exacerbate pressure differentials to lubricate strata faults and cause increased strata movement, which may not necessarily be subsidence, but also lateral shearing.

[0020] Protection from various strata layers and the fluid pressure within said strata are, generally, provided by well conduit linings hung from a surface wellhead, commonly referred to as casings, while protective well linings hung from a previous casing are, generally, referred to as liners.

[0021] Well construction comprises boring through the subterranean strata, placing protective conduit casings or liners, and cementing the conduits in place; prior to using the conduit casings and/or liners for further boring and/or as a secondary pressure barrier about a production or storage tubing and associated subterranean completion equipment. Production tubing, packers, control lines, subsurface safety valves and other completion equipment are installed within the casing and/or liner conduits to provide a primary completion pressure ban-icr within said secondary casing and/or liner barriers that prevent the unplanned escape of fluids from a well into the subterranean strata or surface environments.

[0022] The intermediate annulus between the completion and casing and/or liner conduits is, generally, a void space used to monitor the status of the primary barrier. This annulus may also be used during well construction when a heavy fluid is present within the annulus and/or blowout preventers are placed on the wellhead to provide well control to, for example, place a gravel pack. Once the completion is installed, the blow out prcventers must be replaced by the well's valve tree, generally referred to as a Xmas tree. The intermediate annuli, generally, become fluid tilled voids used for monitoring the primary and secondary barriers, but they may also be used to. for example, provide gas lift to the completion production conduit in wells that are generally incapable of producing significant quantities on their own without stimulation. Other power fluids, such as injected water, may also be circulated through the annulus to operate a jet or a hydraulic pump; or, alternatively, a rod pump or pump jack may also be used for wells requiring stimulation to produce in meaningful quantities.

[0023] It should be understood that the Xmas tree. wellhead and casings are generally the first and last barriers between subterranean fluids and the surface environment, wherein the failure of said casings and completion components deep within a well, generally, have access to annuli passageways connected directly to surface, hence the failure of wells casings kilometres below the earth's surface may represent a serious problem to the surface environment.

[0024] Movements or shifting of the subterranean strata from, for example, subsidence of the heavy overburden, hydration and activation of shale, or flowing of mobile salts.

can adversely affect and damage casings, liners and completion components through the application of collapse, burst, tensile and/or compressive forces.

[0025] The conventiona' remedy for damaged subterraneanly installed casings, liners and/or completion equipmcnt is their removal through what are generally termed "fishing" operations, since damaged equipment may be difficuli to catch and remove, wherein the ability and associated probability of engaging or "catching" and "removing" the "fish" or damaged equipment is uncertain. "Fishing" items that have fallen downhole can be undertaken using various jointed or coiled strings, for example wireline or coiled tubing, whereas heavy duty hydraulic workover units and/or a drilling rigs are conventionally used for fishing of heavy components such as casings, liners and completion equipment. Additionally, when damaged subtcrranean equipment cannot be "fished" from the well it may bc ground or milled into small pieces with a rotary drilling rig or hydraulic workover unit to facilitate its removal using the circulating system to lift said small pieces.

[0026] Failures of well components above the lower end of a well are particularly problematic because intermediate well damage may prevent access to the lower end of the well and/or expose lower end well pressures to upper end well components unsuited for such pressures or the forces associated with such abnormal pressure.

[0027] Unfortunately, the failure of downhole components and their associated primary and secondary barriers may expose various other well components to forces and pressures that may cause further failure and, ultimately, the unintended release of subterranean fluids to the surface, or other permeable subterranean formations. For example, as casing bathers are conventionally designed to withstand the pressures at the lower end depth of casing placement, typically referred to as the "casing shoe," when a secondary deep casing barrier fails and deeper subterranean pressures are placed within the sulTounding annulus void, the shallower and lower pressure resistant tertiary casing barriers may have insufficient pressure bearing capacity for said deeper pressure communication and may also fail, and so on and so forth, until the final barrier fails and an unplanned release of fluid from a well occurs.

[0028] Furthermore, fishing operations for heavy workover units and drilling rigs are particularly difficult and dangerous within a pressurized environment resulting from such failures, where fishing equipment must be snubbed into a well through the blowout preventer while damaged equipment is stripped out of the well through blowout preventers, which must be opened and closed around the varying diameter of tools joints and pipe bodies for each joint snubbed in or stripped out, wherein the design of the blowout preventers requires a circular circumference, and hence canno not seal against deformed conduits.

[0029] Within explosive hydrocarbon environments, where repeated wear and tear from snubbing and stripping operations may weaken the sealing capacity of blowout preventers, leaking of hydrocarbons can occure. Snubbing and stripping operations are considered extremdy risky operations by industry, wherein snubbing and stripping practioners are considered to be the highest risk tolerance workers within the industry, purportedly out of necessity rather than choice.

[0030] Since the failure of various well components, like casings, liners and the surrounding sealing cement can provide leak paths that are not necessarily accessible to kill fluids during a well kill operation or stoppable by the wellhead or blowout preventers, and wherein the pressures exerted during a kifi operation may aggravate said leak paths, the failure of downhole conduits poses a serious risk. Additionally, since snubbing and stripping blowout preventers are engaged to the existing wellhead and/or Xmas tree, they may not provide the necessary blow out protection in instances where well casings have failed.

[0031] Accordingly, a need exists for coiled string operations that can re-establish access or passage to the lower end of a well through the debris and/or damaged walls of an intermediate well conduit failure to provide access for isolating production from damaged well equipment sections, e.g. using the apparatus and method of GB 1111482.4, prior to repairing a damaged section or abandoning the damaged section of a well; wherein coiled string operations may be more easily and safely canied out through pressure control equipment without adversely affecting or further damaging subterranean well equipment with the pressures of a heavy fluid well kill; and whereby the conventional need for expensive and potentially more dangerous fishing and milling operations, using a hydraulic workover unit or drilling rig are not necessary.

[0032] Additionally, a need exists for using exposives axially within a well and absorbing axial fluid pressure shocks or fluid hammer effects upon well equipment when using focused explosives, and wherein a further need exists for focusing of the axial fluid shock or fluid hammer effect in a selectively oriented direction to aid in re-establishing access to the lower end of the well through intermediately damaged well bore walls.

[0033] Well component failure can also occur as a result operational wear from using a well, particularly with regard to thermal and operation cycling when producing and shutting in production. Since subterranean strata generally gets hotter with depth, due to the heat radiated from the earth's molten mantle core, produced fluids can carry that heat from the strata and cause components of a well to expand with production and contract when production is stopped as shallower, lower temperature strata, less affected by the molten mantle core, cool the various portions of the completion. The cycling of production and production shut-in causes associated expansion, contraction, pressure ballooning andior movement of well components that may repeatedly stress and/or erode said components to the point of failure.

[0034] Conventionally, movement of the production conduit strings, which are placed within cernented-in-pace liners and casings. is facilitated by applying tension during the installation of said production conduit strings to reduce physical movement and associated wear at the expense of pbcing additional stresses upon components which may be aggravated by thermal expansion and contraction.

[0035] Various conventional provisions are available for allowing movement of components, such as expansion joints to absorb movement, which may use seal stack mandrels at the lower end of the production conduit string within a polished bore receptacle (PBR) engaged to a liner top packer or production packer secured to said casings, wherein the expansion joint reduces the stresses associated with thermal expansion and contraction, but increases physical movement and associated wear and tear on moving completion components during cycling o production and production shut-in.

[0036] Accordingly, the well completion may comprise a simple tubing string within a casing with a valve tree at its upper end and a production packer at its lower end with tensioned tubing between, or it may have. e.g., subsurface safety valves and associated control lines, sliding side doors for opening and dosing a passageway between the production conduit and intermediate annulus, PBR's, seal stack mandrels, jet pumps. hydraulic pumps, rods, side pocket mandrels for associated gas lift valves, and/or various other completion components, each of which may fail with operational movement, wherein movement of the completion and/or movement within the surrounding strata may damage the well bore's walls, thereby making the piloting of a tool string through failed components conventionally difficult.

[0037] Over the life of a well, completion components and well production casing or liners and conduits may be adversely affected by: chemically corrosive fluids; solids and fluids erosion; subterranean temperatures and/or pressures causing flexure, expansion and/or contraction; vibration, wear or frictional deformation from interaction between various downhole well completion components or from drill strings, wireline, coiled tubing or other tools operating on or adjacent to completion components; as well as plastic deformation caused by strata shearing, thrusting or subsidence movement from, e.g., movement of mobile subterranean salt formation or overlaying pressurized overburden strata forces on produced and depleted formations causing slumping or shifting andlor movements of strata due to hydration or lubrication of shale, clays or other strata within the overburden due to water ingress from natural or induced faults, fractures, water floods and/or faulty well cement isolation from water bearing formations, water floods or natural water drives.

[0038] Various adverse conditions can render a well inoperable from a pressure and fluid integrity perspective and/or prevent deployment of a downhole apparatuses necessary to, for example, repair the effected portions of a well, suspend portions of a well for later repair, abandon portions of a well that cannot be repaired and/or side-track portions of a well to provide further production.

[0039] A need exists for accessing various portions of a well through differing types of debris and damage using less intrusive coiled string operations through an existing pressure control envelop to provide access through a damaged portion for other coiled strings usable to repair or abandon a section or isolate pressures from a damaged portion to provide safer operations than, e.g., jointed pipe stripping and snubbing operations.

[0040] As casing and/or liners are, generally. cemented within the strata even minor movements of the strata around conduit casings and liners may cause said conduits to become oval in shape while more severe movement can collapse or shear said conduits. Rupture of various components within a well may also expose other components to subterranean pressures for which they were not designed. for example, if a secondary conduit harder, such as the production casing, is leaking from wear caused by movement of the tubing and the tubing then ruptures, pressure could be placed on the intermediate and surface casings, which could cause them to burst and release fluids to the environment.

[0041] Attempting to fish or mill damaged components that are not axially aligned with the centre of a well bore can lead to thadvertent side-tracking of a well, wherein access to the original and damaged well bore may be lost and potentially cause a serious pressure control situation as pressures continue to leak through the damaged portion, which may no longer be accessible as a result of the incidental side-tracking.

[00421 A need exists to traverse axially discontinuous portions through an intermediate well bore failure without side-tracking the well during repairs and/or accessing a proximally axial contiguous passageway, so as to access and isolate pressures from said failure, at their source.

[0043] Temperature cycling from, for example, repeatedly starting and stopping production can adversely affect a completion, casing and/or liner components, while significant temperature increases in a confined annulus can cause significant pressure and may plastically collapse or burst well components. Component failures from, for example, a tubing leak at the upper end of tubing string may not burst the production casing. but may increase the pressure within the annulus sufficiently enough to collapse tubing at the lower end of the well, when combined with the hydrostatic pressure of the fluid within the annulus.

[0044] A need exists for less intrusive coiled string interventions capable of, for example, providing a passageway through a tubing collapse and then repairing said tubing collapse with, for example, an expandable metal patch, to allow, e.g., bull-head killing of a pressurized reservoir through the repaired production tubing.

[0045] Alternatively, the build-up of scale within tubing over the life of a well can be significant and may choke off production significantly. A need exists for tools capable of engaging and cleaning scale debris from a production casing to provide an access passageway through the tubing to, for example, set plugs within nipples.

clean downhole valves, side-pocket mandrels and/or inject or use a wireline dump bailer to place chemicals to further clear scale from various downhole well components.

[0046] Accordingly, over the productive life of a well, many factors may adversely affect the components of the well and prematurely end the useful life of a portion, the entire well or its economic life, whereby the suspension. abandonment and/or side-tracking of all or a portion of the well is necessary, but impractical with conventional means.

[0047] A need exists for a more cost effective means of providing access to a well portion clogged by debris or that has been damaged.

[0048] Passage of both fluids and tooling within a well. may be adversely affected by, e.g., debris within a bore from sand production from a reservoir or shale production from a flow cut conduit or scale from production, or they may be adversely affected by deformation of conduits by movement of the surrounding strata, differential pressures across conduits and/or wear and tear from operation of the well.

[0049] A need exists for the coiled string compatible passage of downhole apparatuses and fluids through the proximally circular and deformed circumferences of a well bore.

[0050] The need for fluid or tool communication is particularly acute during the suspension, side-tracking and/or abandonment of a well bore, because subterranean pressures within a bore must be sealed from depleted fonnations and the surface environment.

The prevention of fluid communication and/or loss of fluids from a deposit into other depleted and/or permeable formations or strata factures; and/or the protection of a reservoir deposit or production stream from, e.g., water ingress are important to our economy.

[0051] A need exists to access passageways below an intermediate well bore failure without removing surface well barrier pressure control envelopes to reduce the risk of unplanned releases of well fluids that endanger the surface environment, endanger sensitive strata formations, e.g.. ground water horizons, and waste presently unrecoverable subterranean deposits that may be recoverable later with using techno'ogy that has not yet been invented.

[0052] Various aspects of the present invention address these needs.

SUMMARY

[0053] Accordingly. preferred embodiments of the present invention provide a method (1, 1A-IAE) of using a tool string (8. 8A-8AE) and downhole device (3, 3A-3AE) with a circumferential adaptable apparatus (2, 2A-2AE) to urge access or passage through a subterranean well bore's (10) dissimilar contiguous passageway walls (9); formed by frictionally obstructive debris (18) within or at least a partially restricted circular or deformed circumference thereof.

[00541 Preferred embodiment use at least one associated axial pivotal member (7, 7A-7AE) flexibly hinged to at least one shaft segment of a plurality of movable shaft segments (6, 6A-6AE), wherein the embodiments are usable to operate a tool string comprising a deployment string (8) with lower end coiled string compatible connector (17) engaged to at least one circumferential adaptable apparatus (2) and at least one downhole device (3). Tool string embodiments (8A-8AE) are deployed in and placed or removed through a well bore's (10) upper end into or out of a well borc's (10) lower cnd; through intermcdiatc dissimilar contiguous passageway walls (9) formed by first (4, 4A-4AE) and at least a second (5, 5A-5AE) wall portions of substantially differing effective circumferences andlor debris therein.

[00551 Preferred embodiments provide interoperability between a tool string's (8) tools which comprise axially orienting shafts and members of said tools relative to a dissimilar contiguous passageway walls (9) using a circumferential adaptable apparatus's (2) engagement with dissimilar contiguous passageway walls (9) to selectively orient the tool string (8) and traverse a pilotable passageway between or further deform a wall portion thereof to form a pilotable passageway through said dissimilar contiguous passageway walls (9), wherein interoperability between the tools deployed by the tool string (8) is usable to urge access or passage of the tool string (8) through fnctionally obstructive debris within or at least partially restricted circular or deformed circumference of wall portions (4, 5) forming said dissimilar contiguous passageway walls (9) of a well bore (10). to a lower end thereof.

[0056] Various related embodiments may use a downhole actuation device, wherein said interoperability comprises using said string's (8) tension and/or at least one actuating downhole device (3).

[0057] Various other related embodiments may use at least a second actuation downhole device (e.g. 3, II. 23) usable to operate said tool string by disposing and selectively orienting: at least one downhole device (3); at least one axial pivotal member (7); at least one shaft segment; at least a second shaft segment of said plurality of movable shaft segments; and/or the deployment string (8); to selectively disposed the tools of said tool string radially and/or axially, to selectively orient the tool string within a dissimilar contiguous passageway walls (9) and well bore (10).

[0058] Various other embodiments are usable with a circumferential adaptable apparatus (2) having a fluid passageway (24) and/or orifice (28) usable to selectively control fluid communicate within the well bore (10) and operate the tool string.

[0059] Other embodiments may comprise a circumferential adaptable apparatus (2) with a valve (e.g. 11, IlAl, I IT, IIU) and/or permeable membrane (e.g. 27, 27T) usable to selectively control fluid communicate within the well bore (10) and operate the tool string.

[0060] Still other embodiments may use an actuating downhole device with a positive fluid displacement valve (e.g. 1 IA, 1 1U) and/or momentum vibrator (12, 12A, 12U), which are usable to repeatedly move and minutely reorient and operate a tool string to improve urging access and passage through frictional walls.

[0061] Various embodiment may use an actuating downhole device (3) compnsing a hydraulic, electric and/or explosive downhole device.

[0062] Related embodiments may use explosive downhole devices comprising explosive perforating (20, 201, 20.1, 20M) and/or explosive sculpting (19, 191, 19J, 19M1, 19M2) downhole devices (e.g. 3E, 3F) operable upon at least part of a dissimilar contiguous passageway's walls (9).

[0063] Other related embodiments (e.g. IG-1K, 1M. 1W, IY) may comprise focusing, and/or absorbing hydraulic energy and/or explosive energy using an axial pivotal member (7) to operate a tool string when further deforming at least part of a dissimilar contiguous passageway's walls (9).

[0064] Various embodiments may use motor actuating downhole device (3) using electrical or hydraulic energy (e.g. 21, 21L1, 21L2. 21L3), [0065] Related embodiments may use an actuating downhole device and/or a circumferential adaptable apparatus (2) comprising a plurality of movable shafts with: a helical nodal rotor shaft (e.g. 6A2, 6U2) within an associated helical nodal stator (e.g. 6A3. 3AEI, 3AE2) housing shaft; or an inner shaft within an encompassing out housing shaft with opposing turbine Nades (62) on one or more of the inner or outer encompassing shafts; wherein one shaft rotates relative to the other shaft via a differential fluid pressure applied to said helical nodes or turbine blades to communicate fluids and operate said tool string.

[0066] Various embodiment may selectively urge the expansion or collapse of an axial pivotal member (7) using an actuating downhole device to dispose at least a second shaft segment relative to a flexible hingc's cngagement to the shaft, wherein the expansion or collapse of an axial pivotal member (7) controls its effective diameter and operates, orients, engages or disengages the tool string to or from at least part of said dissimilar contiguous passageway walls (9).

[0067] Various embodiments may compnse functionally shaped: controllably defoimable material (e.g. 2A. 3D2, 22P. 15Q, 15R. 1ST, ISV, 220, 30, 300) and/or substantially rigid material (e.g. l4S, 15D. 26T1-26T2, 26AA-26AC, 29, 29T) to selectively operate said tool string.

[0068] Other embodiments may use an axial pivotal member (e.g. 7N, 7P, 7Q, 7R, 7Tl - 7T3) comprising a packer (34, 34A, 34U. 34AE), bridge plug (e.g. 35, 35A, 35U, 35Y1-35Y2). pedal basket (e.g. 22. 22N, 220, 22P, 22T1-22T2) and/or flexible membrane (e.g. 15, ISA, 15Q, lSR. 1ST, ISV).

[0069] Various related embodiments may use an axial pivotal member (7) with at least one mechanic aim linkage (e.g. 14B, 14C, l4Q, 14S, 14T1-14T5, I4AEI-14AE4) and/or a wheeled mechanical linkage (e.g., 26T1-26T2. 26AC, 26AB1-26AB2, 26AA, 26AE1-26AE2) to further operate and selectively orientate said tool string.

[00701 Still other embodiments may use the tool string to forcibly deform a dissimilar contiguous passageway's walls (9) radially outward and/or axially downward to, in use, urge said access or passage.

[0071] Various related embodiments may comprise operating a cutting downhole device (3E, 30. 3L1, 3AE) on at least one shaft (6) of a plurality of shafts and/or an axial pivotal component (7) to forcibly deform at least a part of said dissimilar contiguous passageway walls (9).

[00721 Other related embodiments may use of a mechanical cutter (13), chemical cutter and/or explosive cutter downhole device (3) to deform said walls (9).

[0073] Still other embodiments may operate a wedging downhole device (e.g. 37, 37A, 37J,) on detachable shaft and/or as part of an axial pivotal component (7) to deform a passageway wall (9) using differential fluid pressure across the wedge.

[0074] Various embodiments may use at least two shaft segments with an intermediate spring like joint (e.g. 23, 23A, 23Ti-23T4, 23AE1-23AE2), knuckle joint (e.g. 16, l6C, l6E, iSV), hinged joint (e.g. 25, 250, 25Q, 2STl-25Tl3, 25AC1-25AC2, 25AB]-25AB2, 25AA1-25AA2, 25AE1-25AE4) and/or ball joint to operate and selectively orientate a tool string.

[0075] Various embodiment may use at east a second shaft segment axially movable within another encompassing shaft segment, while other embodiments may use a plurality of moveable shaft segments further comprising a substantially flexible shaft (e.g. 6B2, 6E1) and/or a substantially rigid shaft (e.g. 6B1, 6E2-6E3, 6T1-6T10, 6Ti- 6TlO, 6AE1-6ABII, 6C1-6C2. 15D) to further operate said tool string.

[0076] Other embodiments may use substantially rotating (e.g. 6B2, 6C2, 6E1. 6L1, 6L5- 6L6), substantially stationary (e.g. 6A. 6B1, 6Cl, 6D. 6E2-6E3. 6L2-6L4, 6L7, 17L7), or combination thereof, shaft segments usable to further operate said tool string (e.g. lA-IS, 10).

[0077] Various other embodiments may use dogs, slips, shear pins and/or mandrels as a holding downhole device (3) within an associated receptacle to selectively engage moveable shaft segments.

[0078] Various embodiments may comprise an arrangement of shafts (6) and axial pivotal components 7) to fonii a hole finding tool (e.g. 2A-2C, 2E-2F, 3Z) or carry a hole finder downhole device (3) usable to locate an accessible or pilotable passageway and traverse through a dissimilar condguous passageway waHs (9).

[0079] Various i-elated embodiments may operate an image thgging downhole device (3) selectively oriented by a circumferential adaptable apparatus (2) to, in use, image the dissimilar contiguous passageway walls (9) for further selective orientation, pilotable traversing and/or selective deformation using empirical imaging data from said logging downhole device.

BRIEF DESCRIPTION OF THE DRAWINGS

[0080] Preferred embodiments of the invention are described below by way of example only, with reference to the accompanying drawings, in which: [0081] Figures 1 to 2 and 2A depict prior art diagrams and a graph of a slickline cement retainer's deployment and usable diameters of conventional inflatable packer downhole devices.

[0082] Figures 3 and 4 illustrate an embodiment of a wireline, coiled string or jointed pipe tool string embodiment for access or passage through horizontal or inclined subterranean well bore dissimilar contiguous passageway walls, wherein removal of the debris is not necessary.

[0083] Figure 5 depicts a prior art flexible shaft and boring bit, while Figures 6 to 20 depict wireline, coiled stnng or jointed pipe tool string embodiments usable for access or passage through subterranean well bore dissimilar contiguous passageway walls.

[0084] Figures 21 and 22 show prior art shaped peiforating charge downhole devices.

[0085] Figure 23 shows an embodiment of a shaped charge sculpting circumferential engagement apparatus deployable on wireline. coiled string or jointed pipe to provide access or passage through a subterranean well bore's dissimilar contiguous passageway walls.

[0086] Figures 24 to 26 depict rotary cable operations apparatuses of the present inventor usable with the present invention, wherein Figure 25 shows an embodiment usable with said rotary cable tools.

[0087] Figures 27 to 32 illustrate various parts of axial pivotal member embodiments usable to form a circumferential engagement apparatuses of the present invention.

[0088] Figures 33 to 41 depict an embodiment of the present invention illustrating a substantial expanded to deployment diameter ratio.

[0089] Figure 42 shows a reduced friction embodiment of the present invention usable for access or passage through subterranean well bore dissimilar contiguous passageway wafls.

[0090] Figures 43 to 48 illustrate various wheded skate embodiments of the present invention.

[0091] Figure 49 shows a prior art shot gun and Figure 50 depicts a explosive compression piston of the present inventor.

[0092] Figures 51 to 56 depict various tool string embodiments of the present invention usable for access or passage through subterranean well bore dissimilar contiguous passageway walls.

[0093] Figures 57 to 64 show an embodiment of the present invention usable for access or passage through subterranean well bore dissimilar contiguous passageway walls as a hydrodynamic fluid bearing cutting tool string.

[0094] Embodiments of the present invention are described below with reference to the listed Figures.

DETAILED DESCRIPTION OF THE EMBODIMENTS

[0095] Before explaining selected embodiments of the present invention iii detail, it is to be understood that the piesent invention is not limited to the particular embodiments described herein and that the present invention can be practiced or carried out in various ways.

[0096] It is to be understood that when explaining the various methods (I) embodiments (1A-IAE) using a circumferential adaptable apparatus (2) embodiment (2A-2AE) to pilot any present inventor, conventional or prior art downhole devices (3, 3A-3Z) deployed at the lower end of a string (8) comprising, e.g., slickline. electric line, coiled tubing or jointed pipe using a coiled string compatible connector (17). the described arrangement and assembly of tools at the lower end of the connector (1 7) comprise to& stnng embodiments (SA-8AE) with interoperability between tools being usable to urge access or passage through a subterranean well bore's (10) dissimilar contiguous passageway walls (9).

[0097] Referring now to Figure 1, which illustrates an elevation view of a prior art pedal basket cement retainer (66) in various deployment stages (72-75), representive of most related slickline prior art dealing primarily with securing of tools andlor dumping or debris with a bailer and/or placing small tools through a constant circular diameter well bore or, for example, through the circular circumferences of a tubing tail pipe (76) into the production liner or casing (77); as well as anchoring of tools (68) within the tubing (76), liner or casing (77).

[00981 In the illustrated example prior art deployment, the cement retainer (66) is first deployed (72) in a collapsed state to below the tail pipe (76) and the upper actuator (3, 69) is used to actuate the slips (68) anchoring the retainer (66) to the casing in the second phase (73). The third phase of deployment (74) uses the second downhole actuating device (3, 70) to actuate the pedal basket (22) within the casing (77). The final phase of deployment (75) is to remove the upper actuator (70) and engagement shaft leavthg the central shaft (71) used to actuate the slips (68) and pedal basket (22) within by axially actuated shafts along its length using the downhole actuators (69, 70).

[0099] Numerous conventional actuators are useable to perform these common actuation tasks as downhole devices of the present invention, wherein the cited references provide various modifications this conventional pradice dating to the beginnings of 1940's.

[00100] While prior art is not completely incapable of traversing substantially differing circumferences formed between the tubing (5, 76) and casing (4, 77) or open hole (79 of Figure 2), it is important to emphasise that conventional technology presumes that the tubing and casing are not. e.g., crushed or collapsed, and wherein circular circumferences provide relatively low friction factors and whereby, e.g., a wireline entry guide is generally used at the lower end of a tailpipe (76) protruding within a casing (77) bore to aid traversing the differing diameters. Hence, while both the present invention and prior ar are suited for a tail pipe, the present invention provide significant benefit by not requiring a wireline entry guide or circular circumferences, wherein the present invention also provides access or passage past debris within well

bore walls that prior art cannot.

[00101] Figures 2 and 2A show a diagrammatic elevation cross sectional view through a subterranean well bore of a prior art coiled string deployable inflatable packer or bridge plug, and a chart showing the expansion capabilities of conventional inflatable packers and bridge plugs. respectively. As shown in the Figure 2A chart, reproduced from the cited brochure of an industry leader in the art of inflatable technology, TAM International Inc., the deployment diameter of a conventional inflatable membrane packer is 3.75 inches if you wish to inflate the packer to engage the sides of a 9 5/8" casing with an inside diameter of approximately 8.5 inches for the average North Sea wall thickness production casing. The deployment diameter of an element (labelled "ci." in Figurc 2A) of 3.75 inches (labelled " in Figure 2A), may be acceptable for a 4 1⁄2 inch outside diameter tubing weighing 12.6 pound per foot with a drift diameter of 3.833 inches, but it will not fit through heavier wall 4 1⁄2 inch outside diameter tubing or smaller diameter API tubing and still engage or hold within the walls of said 9 5/8" casing. Generally, this is not a significant issue because the primary purpose, as demonstrated by the chart, is to hole differential pressure, wherein said 3.75 inch deployment diameter inflatable packer is capable of holding between 3,000 and 4,000 pounds per square inch or between 206.9 and 275.8 bar differential pressure. An inflatable packer capable of passing through the 2.165 inch drift diameter of API 2.875 inch outside diameter tubing weighing 8.44 pound per foot could have a deployment diameter of 2.125 inches with a maximum expandable conduit circumference engagement diameter of between 6 inches and 7 inches according to said leading manufacturer's chart.

[00102] According, as shown in Figure 2, if a conventional inflatable packer (78) capable of being deployed on as string (8) through the 2.165 inside drift diameter of 2 7/8 inch outside diameter tubing (76) into an 8.5 inch inside diameter casing (77) cemented (80) within an open strata bore (79), generally sized to a minimum of 12 1⁄4 inch inside diameter. and referred to as "open hole," then said conventional packer is not capable of either engaging the casing or the open hole with the slip segments (82) secured to its membrane (81) at its maximum inflation.

[00103] Referring now to figures 3 and 4, which depict a diagrammatic elevation cross section along a horizontal well bore (10) with line A-A associated with the Figure 4 cross section through line A-A of Figure 3 transverse to the well bore axis, illustrating embodiments (lA, 2A) of method (1) and apparatus (2) for access or passage through dissimilar contiguous passageway walls (9) using a tool string (8) embodiment (8A) and downhole device (3), which are usable when, e.g., removal of debris is not necessary. Traversing and/or plugging a horizontal well bore (10) without debris removal may be necessary during, e.g., abandonment operations to support a cement like settable sealing material and prevent the heavier cement like fluid channelling on the lower end of the horizontal while lighter downhole fluid channels along the upper portion of the well bore and, thus, contaminate the cement like material to weaken it, thus preventing its setting and/or sealing for said abandonment.

[00104] The tool siring (8) is traversed through a pilotable passage between wall portion (4) of open hole (4A) dissimilar to another open hole (SA) wall portion (5) further complicated by debris (18) therein forming, in amalgamation (9A), the dissimilar contiguous passageway walls (9) of a well bore (10), wherein the tool string embodiment (BA) may comprise, e.g., slickline, electric line, coiled tubing orjointed pipe with a lower end coiled string compatible connector (17) engaged to circumferentially adaptable apparatus (2A) comprising a plurality of shaft segments (6). Shaft segment embodiments (6A1-6A3) may comprise an encompassing shaft (6Al) with rotor (6A2) and stator (6A3) shafts usable as a momentum vibrator (12) and positive displacement valve (11) embodiments (l2A and 1 IA, respectively) with orifices (28) for fluid intake (32) and exhaust (33) from the vibrator and valve with a spring like joint (23) embodiment (23A) interoperable with an axial pivotal member 7) embodiment (7A) comprising a downhole device (3) embodiment (3A) further comprising an inflatable membrane (15)enibodimeni(l5A).

[00105] The tool string (8A) may be urged, using surface applied fluid pressure (31), through the substantially differing diameters of the open hole (9A) from, e.g.. a near vertical to near horizontal inclination using differential pressure across embodiments (34A, 35A) of a packer (34) or bridge plug (35), when urged to a desired disposition along the well bore (lO), wherein a fluid passageway (24) embodiment (24A) formed by the positive displacement valve (I IA) cavity between, e.g., a helical rotor (6A2) and stator (6A3) is fluidly routed between the left and nght orifices (28) to use the difference between surface (31) and bottom hole pressure (32) to actuate the positive displacement which is fluidly exhausted (33) with axial movement of the string (8A), and wherein the passageway 24A) may also be selectively and fluidly connected via, e.g., a pressure activated valve, to fill and deplete the fluid filled deformable material membrane (1 5) to selectively exhaust fluid to collapse said membrane (1 5A) when piloting a restricted effective diameter of the dissimilar contiguous passageway walls (9A) and intake fluid to expand said membrane when said effective diameter increases using said positive displacement valve interoperability between the differential pressures of applied surface pressure (31) and bottom hole pressure (32) across the packer (34).

[00106] Figure 5 depicts a diagrammatic elevation view of a prior art boring bit (13) and the flexibility of its combined flexible and rigid shaft (36) usable within any present embodiment as a downhole device (3) and/or hole finder, wherein various other flexible shaft arrangements described in application publication 0B2484166A of the present inventor are also combinable with the method and apparatus of the present invention.

[00107] RefelTing now to Figures 6 and 7, illustrating a diagrammatic elevation view of a slice along the axis and a diagrammatic plan cross sectional view transverse to the axis along two subterranean well bore's (10) dissimilar contiguous passageway walls (9E, 9F1, 9F2), respectively, showing method (1) embodiments (lE, IF, 10) and apparatus (2) embodiments (2E, 2F, 20) usable with a tool string (8) embodiments (SE, SF, 8G) and downhole device (3) usable to access or provide passage through, e.g., collapsed well bore walls resulting from strata movement (38) and/or wall portions with scale debris from production.

[00108] A string (8), preferably comprising a coiled string, but usable with, e.g., jointed pipe or jointed shaft strings, forms part of the tool string (8) comprising circumferential boring or expandable wedging (37) downhole devices (3E-3G) comprising any mechanical cutting tool (13), e.g. a rotary drill bit for metal and/or rock, wedging downhole device (37) oi axial pivotal wedge, engagable with a circumferential adaptable apparatus (2E-20) comprising a plurality of shafts (6) and an axia' pivotal member (7). A flexible shaft (36, 6E1) is usable, when oriented by an axial pivotal member (7), to selectively pilot between wall portions (4E and 5E, 4F and 5F. 4Fi- 4F3 and 5Fi, 4F4-4F6 and 5F2, 4F7-4F9 and 5F3) of substantially differing effective diameters, thus forming dissimilar contiguous passageway walls (9), within a well bore (10). An arrangement of a plurality of shafts (6) comprising a flexible shaft (6Ei) may be rotated or extended and retracted within or through encompassing housing shafts (6E2. 6E3) with an intermediate flexible (16) knuckle or ball joint (l6E) selectively alignable with an axial pivotal member (7, 7E) to pilot and traverse a tortuous path through. e.g., a collapsed subterranean well bore. A series of various proximally axially contiguous pilotable passages (4Fl-4F3, 4F4- 4F6, 4F7-4F9) may be accessed and deformed to a larger effective diameter to provide passage wall portions (5Fl, 5F2, 5F3, respectively) to allow a still larger deformation of wall portion (4F) to wall portion (5F) to provide an enlarged passageway for tool passage using boring (13, 3F) and/or wedging (37, 30) downhole devices (3) and/or axial pivotal members (7) of a circumferential adaptable apparatus (2).

[00109] Figures 8 and 9 depict diagrammatic isometric views of well bore (lO) walls (9) before and after being deformed by subterranean strata movement (38), respectively, while Figure 10 shows a diagrammatic isometric view of a prior art approach to gaining access or passage to the Figure 9 well, which has resulted in a side-track of the subterranean well bore's (10) due to its dissimilar contiguous passageway walls (9). The well bore (10) walls (9) comprising, e.g., casing (9B2) and production tubing (9B 1) are deformed by moving strata forces (38) forming substantially differing circun-iferences (4B, SB) that cause the tubing to become conventionally unusable and effectively debris (18) within the wellbore.

[00110] Side-tracking of a damaged portion of a well bore without first abandoning the lower section of a well bore (10) fluidly connected with a reservoir is particularly risky, because once the side-track has occurred, it is virtually impossible to re-enter the original dissimilar contiguous passageway since an axially deployed string always favours the axially aligned side-track; however fluid from the reservoir is free to follow through aiiy passageway not restricted by fluid capillary friction, hence the reservoir cannot be effectively abandoned because the heavier and more viscous kill weight mud and/or cement like fluids cannot be injected through the same pore or passageway spaces and/or become contaminated from percolation of buoyant lighter and more fluid reservoir gases and liquids axially upward.

[0100] Killing of an intermediately collapsed well bore is difficult because reservoir fluid may continue to percolate through various permeable pore spaces or strata fractures that are not fillable with kill weight fluid, typically referred to as kill weight mud due to its composition and consistency; hence it may not be possible to kill the well with heavy mud to allow replacement of the surface valve tree with a blowout preventer. Accordingly, conventionally high risk snubbing and stripping operations may be necessary when a well cannot be killed effectively and conventional hydraulic workover units, drilling rig may be needed.

[0101] The boring capabilities of conventional and prior art boring arrangements (39), e.g. coiled tubing arrangements and/or rotary cable tools of present inventor (GB247 1760), without the piloting capabilities of a circumferential adaptable apparatus (2), may be unsuited for accessing and providing a passageway to allow abandonment of the damaged well, because of their propensity to deflect off of the substantially differing effective circumferences of deformed wall portions (4, 5) and side-track the well, thus losing access to the wells lower fluid reservoir fluid connection.

[0102] Referring now to Figures 11 to 13, which show diagrammatic isometric views of the well bore (10) walls (9) of Figure 9 and illustrate method (I) embodiments (lB. IC, ID) and apparatus (2) embodiments (2B, 2C, 2D) usable with a tool string (8) embodiments (8B, SC, SD) and downhole device 3) to provide access or passage through dissimilar contiguous passageway walls (9B1, 9B2), wherein flexible shaft arrangements are used to gradually increase the effective diameter, and wherein progressing to more rigid shaft arrangements are usable to proximally align the upper end of the well bore with the lower end so as to install an intermediate conduit, e.g. an expanded flexible metal pipe encompassing shaft (15D) about an expander downhole device (3D1) at the lower end of an expander shaft (6D), to provide a more pilotable passageway for deployment strings to traverse.

[0103] A tool (SB, SC) string (8) comprising, e.g. slickline or other coiled string, deploying a circumferential adaptable apparatus (2B, 2C) with a plurality of shafts (6) is usable with a flexible rotatable shaft (6B2, 6C2) and lower end mechanical cutter (13), e.g. a rotary boring bit, with an upper end, e.g., positive fluid displacement motor rotary cable tool of the present inventor, electnc or coiled tubing motor compnsing a substantially rigid shaft (6B1, 6Cl) held substantially stationary by an axial pivotal member (7B, 7C), comprising, e.g.. 7T1 and 7T3 of Figures 33 to 41, I4AC-I4AA of Figures 43 to 48 and 7AE1-7AE2 of Figures 57-63, is usable to further deform and provide access or passage through the dissimilar contiguous passageway walls through deformation of the wall portions (4B, SB) of substantially differing circumferences. Various mechanical cutters (13), e.g. the boring cutter (13) of Figure 5 to 7, may be used or the abrasive lateral cutters (13AE) of Figures 57 to 64, or a wedging (3D, 3C), explosive (3M1-3M3) and/or sculpting (19M1-i9M3) downhole devices (3) or axial pivotal members may be used and oriented with the tool string (8), Once assess or passage has been provided, it may be improved by.

e.g., engaging a straddle conduit to reconnect the tubing 9Bl) or expandable conduit (15D) using a wedging downhole device (3D2) to wedge the expandable conduit radially outward with an expander 3Dl) and further deform debris from, e.g., boring to further improve access and passage through frictionally obstructive debns (18).

[01041 Figures 14 to 20 illustrate the proportions of a collapsed 6 5/8" conduit with a 1 inch wall thickness made of very hard 125,000 psi yield strength material; which was described by a major producer who has a significantly number of similarly damaged wells, and has exhausted the obvious conventional practice and prior art, and who asked the present inventor for possible solutions, wherein the wells are in fluid connection with a reservoir and losing access to the lower end of a well bore due to side-tracking is a major risk, and whereby the associated embodiments of the present invention were devised, and wherein a Form 1 application for patent legal protection through the UKIPO was made prior to any public discussions of embodiments herein.

[0105] Figures 14, 15 and 16 illustrate a plan view where Figure 15 in an elevation view with break lines and Figure 16 in an isometric view with the Figure 15 break line portion of the subterranean well bore's (10) walls (9) removed, with dashed lines showing hidden surfaces showing a method (I) embodiment (I H) and a plurality of apparatus (2) embodiments (2H) usable with a plurality of tool strings (8) embodiments (81-1) and downhole devices (3) to provide access or passage through dissimilar contiguous passageway walls (9H) usable with, e.g..: tool strings deploying image logging downhole devices (3) usable to empirically measure, e.g., three dimensional space disposition, orientation, inclination, temperature, pressure and orientation of various walls, as well as look ahead continuation imaging to determine a most likely axial orientation between wall portions (4H and 51-1), necessary for planning and selective configuration of a tool string embodiment for access and passage to the lower end of the well bore (10) below the substantially differing circumferential deformations and/or debris caused by strata movement (38).

[0106] Logging of the maximum force (38H1) plane and minimum force (38H2) plane of strata movement, as well as strata bonding to the collapsed conduit, and strata properties above and possibly below the moved strata, may be possible using an imaging logging downhole device (3) with the string (8) oriented by a circumferential adaptable apparatus's (2H) plurality of shafts (6) and axial pivotal member C) engagement with various wall portions.

[0107] The plurality of tool strings (8), downhole devices (3H) and associated circumferential adaptable apparatuses (2H) may also comprise various preferred coiled strings comprising, e.g., slickline, electric line or coiled tubing or jointed shafts or pipes used within the dissimilar passageway walls (9) for their various properties: comprising, e.g., the ability of coiled strings to be deployed and retrieved relatively quickly compared to jointed pipe to allow more runs in and out of the well bore (10); the ability to more easily rig-up pressure control equipment above an existing valve tree, or Xmas tree, and wellhead as well as seal around a continuous coiled string using, e.g., a stuffing box or grease injector head compared to jointed pipe, snubbing and/or stripping operations; the ability to quickly change logging tools and provide real-rime image logging information using, e.g. electric fine or memory data using, e.g. slickline compared to pulse communicating logging tools at the lower end of a jointed string; or thgging information transmited through the casing using embodiments of the present invention; and the associated ability to make a plurality of tool string runs into and out of the well with various tools, as wells as the ability to make smaller and more controllable deformations of damaged downhole well components, to reduce the risk of side-tracking a well when providing access and passage compared to the jointed pipe operations; whereby the advantage of jointed pipe is, e.g., its ability to more effectively rotate and mill damaged well components into small pieces, once the well can be killed and/or the reservoir fluid connection with surface or sensitive strata formations becomes controllable.

[0108] Additionally, the plurality of tool strings (81-1) and associated deployments may include, e.g.: the above image logging downhole device (3M) electric line deployment; followed by a slickline deployment of an explosive sculpting downhole device (3H) similar to, e.g., (41, 4J, 3Y and 3M1-3M3) wall portions and downhole devices of Figures 7-18 and 19 and Figures 23 and 51, respectively; followed by a slickline deployment of an abrasive milling downhole device (3M) similar to, e.g., the fluid turbine downhole device (3AE1-3AE2) of Figures 57 to 64; followed by slickline deployment of a wedging downhole devices (3M) similar to, e.g., wedging devices (3W, 3Z) of Figures 52 and 56, respectively; followed by a small diameter relatively flexible jointed pipe deployment using a conventional carbide encrusted milling downhole devices (3M) oriented with a circumferential adaptable apparatus (2H) usable to pilot the conventional mill into position; followed by a relatively flexible jointed pipe deployment of an expandable conduit downhole device (31-I) piloted through the dissimilar passageway walls (9) with a circumferential adaptable apparatus (2H); after which the conduit is expanded to provide access and passage through frictionally obstructive debris (18) within or at least a partially restricted circular or deformed circumference of said dissimilar passageway walls (9).

0109] Referring now to Figures 7 and 18 which depict a plan view and the upper end of an elevation view above a break line with dashed lines showing hidden surfaces.

illustrating a method (I) embodiment (11) and apparatus (2) embodiment (21) usable with a tool string (8) embodiment (81) and downhole device (3) to provide access or passage through dissimilar contiguous passageway walls (91). Previous deformation of a wall portion (4) has resulted in a new wall portion (41) providing an axially deeper dissimilar passageway wall (91) formed by and/or usable with a downhole device (31) comprising. e.g., explosive sculpting downhole device (19) embodiment (191) using, e.g.. oriented shape charge downhole devices (3, 3M1-3M3) of Figure 23 or axially downward perforating downhole device (20) embodiments (20J) of Figure 19, oriented by a circumferential adaptable apparatus (21) plurality of shafts (6) and axial pivotal member (7) to further deform the wall portions (41, 51) and further provide access or passage through the dissimilar passageway walls (9).

[01101 Alternatively, the downtiole device (3H) may comprise a boring bit with an upper end motor (2i), e.g., (2lLl) and (2lL2) with associated upper end coiled string compatible connectors (l7L1) and (1712) of Figures 25 and 26, respectively, compr sing said plurality of shafts (6), wherein perforations (201) may be placed to allow fluid circulation if fluids cannot be injected into the reservoir through the well bore's dissimilar passageway walls (9).

[0111] Figure 19 shows a plan view, with dashed lines showing hidden surfaces, depicting a method (1) embodiment (11) and apparatus (2) embodiment (2J) usable with a tool string (8) and downhole device (3) to provide access or passage through dissimilar contiguous passageway walls (91), wherein axially explosive cutting perforations (20) downhole devices (201) may be used to weaken a wall portion (41) and disturbed supporting strata behind said wall portion to aid a wedging (37J) or boring downhole device (3J) engaged to the circumferential apparatus (2J) deployed with a string (8) embodiment (8J) and to further deform said wall portion (41) and provide access or passage through dissimilar passageway walls (9).

[01121 Figure 20 illustrates a diagrammatic elevation view, with dashed lines showing the well bore prior to deformation, depicting a method (1) embodiment (1K) and apparatus (2) embodiment (2K) usable with a tool string (8) embodiment (8K) and downhole device (3) to provide access or passage through dissimilar contiguous passageway walls (9K) by, e.g., using a plurality of coiled string tool stnng (8) deployments (8K), using a plurality of explosive sculpting cutting downhole devices (19K). and/or perforating downhole devices (20K) and alternating deployment of image logging downhole devices (3K) to measure deformation of the explosively deformed dissimilar passageway walls (9). wherein any shaped charges (40 of Figures 21 and 22) may be arranged according to the previous image log data in, e.g., the oriented arrangement (2M) of Figure 23 to provide passage between the upper and lower ends of the well bore (10) in selectively controllable tool string runs and method steps; whereby after gaining access the lower end of the well bore, it may be, e.g., abandoned or suspended to allow repair of the dissimilar passageway walls (9) without a fluid connection to the reservoir during said repair or abandonment.

[0113] Referring now to Figures 21 and 22. which illustrate an isometric view and cross section along the explosive cutting axis of prior art shaped charge (40) technology, wherein any shape and size of shaped charge is available to provide selective control of explosive perforating and sculpting operations. Generally, a shaped charge is comprsed of a liner (45), explosive (48) and case (47). The case (47) defines an interior volume in which the liner (45) is positioned, wherein the liner (45) defines an interior volume (44) and has an opening thereto. The opening is surrounded by a rim portion (46) of the liner (45). whereby the ignition system (43) ignites the explosive (48), which explodes in a pattern associated with the deflector (49), interior volume (44) and casing (47) shape to exit through the rim portion (46) in an explosive cutting force jet (50 of Figure 23) selectively controllable by the various components of the shaped charge (40), which is usable within the present invention to perforate and/or sculpt wall portions (4,5) in a controllable manner according to the orientation of any shaped charge or other explosive andlor associated chemicals forming a chemica' cutter piloted through a deformed passageway of substantia'ly differing circumferences along a well bore's waIls (9) using the present invention.

[0114] Figure 23 shows a diagrammatic cross section view through the explosive cutting axis, with dashed lines showing the well bore walls being further deformed by the method (1) embodiment (IM) and apparatus (2) embodiment (2M) usable with a tool string (8) embodiment (8M) and downhole device (3) to provide access or passage through dissimilar contiguous passageway walls 9M). Using image logging too] string empirical data, a circumferential adaptable apparatus's (2M) engagement and orientation with the dissimilar contiguous passageway (QM) wall portion may be arranged and carried out to provide a selective deployment and sculpting or perforating of a wall portion (4M) to form a larger wall portion (3M) proximally axially contiguous with the desired access and passage of tools using (l9Ml-19M3) shaped charges (40) or perforating (20M) shaped charges (40) oriented within the apparatus (2M) piloted by its shall (6) and axial pivotal member (7) at the lower end of the tool string (8). As explosives may form relatively sharp debris and/or sharp edges on deformed walls, vanous other embodiment are usable to pilot the traversable dissimilar passageway to further deform explosive debris.

[0115] Additionally, the axial firing of explosives presents the problem of transmitting a fluid hammer effect axially within the welihore, whereby the objective is generally to focus or funnel such a fluid hammer away from the surface and toward the walls being deformed. Various apparatus embodiments. e.g., 2X, 2Y, 2W and 2Z of Figures 42, 51, 52 and 56, are usable to absorb and/or focus/direct a fluid hammer effect associated with and similar to axially oriented explosive jets (50).

[0116] Referring now to Figures 24, 25 and 26 which depict rotary cable tools of the present inventor in the Figure 24 elcvation vicw of a slice through the well borc's (10) walls (9L1, 9L2) usable with the Figure 25 isometric view of an embodiment using a rotary cable tool motor and reactive torque tractor and the Figure 26 isometric view of a cable conveyable positive displacement fluid motor rotary cable tool, also usable, with the Figure 25 method (I) embodiment (IL) and apparatus (2) embodiment (2L) comprising a tool string (8) embodiment (8L) for using a downhole device (3) to access or passage through dissimilar contiguous passageway walls (9L). wherein the various functions of (6L2-6L7, 7L2-7L10, 17L2-17L7 and 21L1-2lL3) are further described in application publication 0B2484166A of the present inventor.

[0117] Various elements of a tool string (8L1) may represent both members of a circumferential adaptable apparatus (2L) and a downhole device, e.g., a plurality of shafts segments (6L2, 6L3, 6L4) may also comprise motor downhole devices (3L2, 3L3, 3L4, respectively), wherein the shafts or motors may be those of the present inventor or, e.g., conventional electric or hydraulic downhole motor devices.

Similarly, axial pivotal members (7L2-7L10) may represent various coiled string compatible and pilotable members that extend from the axis of the tool string via a flexible hinge, e.g., the drive wheels of a reactive torque motor tractor (7L2-7L3, 7L9) flexibly extend and retract from a shaft (6L2. 6L4, respectively) via the torque caused by rotation; sealing cup seals (7L4, 7L7, 7L9) flexibly expand and contract from between a shaft (6L2. 6L3. 6L4, respectively) to direct fluid through orifices (28) to a positive displacement fluid motor (21L1-21L3) device (3L2, 3L3. 3L4, respectively); and anti-rotation devices (7L5-7L6, 7L10) for motor devices (3L3, 3L4, respectively) are flexibly hinged to shafts (6L3-6L4, 6L8, respectively).

[0118] Alternatively the motor downhole devices, for example (3L2. 3L3, 3L4), may also comprise electric motors, pneumatic motors which are piloted through andior used to deform restricted passageways via the method (IL) and/or apparatus (2L) of the present invention. A downhole motor (21) device (3L2-3L4) or plurality of shaft segments (6L2-6L4) of a circumferential adaptable apparatus (2L) may be used to, e.g., rotate a shaft (6L1) and lower end boring bit downhole device (3L1) piloted by an axial pivotal member (7L1).

[0119] Accordingly, while the present apparatus (2L) is preferred, the present method (1L) may use various conventional, prior art apparatuses andlor apparatuses of the present inventor assembled in an interoperable combination to form a tool string (8L) to, in use, traverse a pilotable passageway between or further deform a well bore's (10) lower end dissimilar contiguous passageway waIls (9) formed by first (4L) and at least a second (5L) wall portions of substantially differing effective circumferences.

[0120] Figures 27 and 27A depict isometric views of an example pedal (22) embodiment (220) for a pedal basket and an example mechanical linkage arm (14) embodiment (14S) usable together with various other axial pivotal member (7) embodiments (e.g. 70) of the present invention. The flexible hinge (250, 25S) may be formed with, e.g., a deformable material (3001) engagable to a shaft of a circumferential adaptable apparatus (2). The pedal (70) may also be deployed between, e.g., wedging shafts, wherein an engagement wedge shaft (3701) is forced against a wedging shaft (3702) to deform the materal (3001) of the flexible hinge (250). A sealing deformable material 3002). e.g. elastomeric material or coatings, may also be used and placed at the wall engagement to provide a seal to the well bore wall (9).

[0121] The pedal (70) may be deployed in any arrangement, e.g. like that of Figures 28 to 30, to provide engagement with a well bore waIl (9), wherein an orifice (28) for a mechanical arm (14S) engagement may be used to extend and/or retract the pedal (70). The mechanical aim (14S) may also be engaged to multiple axial pivotal members (70) and/or member components, e.g. (7T) of Figure 33, wherein the arm (l4S) is connected between upper (22Tl of Figure 33) and lower (22T2 of Figure 33) pedals (70).

[0122] Referring now to Figure 28 which shows a collapsed plan view of an embodiment (22P) usable with the Figures 29 and 30 expanded plan view and elevation view embodiment (22N, 22P) of a pedal basket (22) usable with various other axial pivotal member (7) embodiments of the present invention. Axial pivotal member pedals (7P). e.g. (70 of Figure 27), may be overlapped and deformed around a shaft to form a collapsed pedal basket (22P) which may be expanded by any means, e.g. by wedging shafts (370 1-3702 of Figure 27) or mechanical arms (14S of Figure 27A) and/or a linkage with an inflatable membrane, to form an expanded pedal (7N) basket (22N). wherein the pedal basket (22N) may focus, support andlor protect, e.g., an elastomeric funnel, bladder and/or fluid inflatable packer/bag or cement like material or, e.g., the forces of a fluid hammer axially transmitted through a well bore by, e.g., an explosive or hydraulic jar.

[0123] An axial pivotal member (e.g. 2P/2N) may also be interoperable with. e.g., shafts (6), passageways in shafts (24). springs, shock absorbers and any other downhole device usable to automatically expand and collapse said axial pivot member so as to retain engagement with or pilot varying substantially differing circumferences as it is traversed through a well bore to, in use, pilot other engaged downhole devices (3), as shown, e.g., in Figures 33 to 42 embodiment (2T). Any material, e.g. carbide to abrade debns during passage or rotation andlor elastorners to seal against wall portion during passage, may be engage to a pedal (e.g. 220 of Figure 27) to provide various downhole functions, wherein recovery of debris is not necessarily the objective, but possibly tool string deployment or displacement and associated intervention with wall portions necessary for piloting or further deforming of a passageway with the deployed tool string or another subsequent tool string.

[0124] Figures 31 and 32 depict collapsed plan view slices across a plane transverse to the shafts axis, usable during, e.g., deployment and prior to expansion downhole or during retrieval of the axial pivotal member (7) embodiments (7R. 7Q, respectively) and membrane (15) embodiments (l5R, 1SQ, respectively), which are usable with various other embodiments of the present invention. Various combinations of axial pivotal members, e.g., a pedal basket (22N of Figures 29 and 30) with the membranes (ISR. l5Q) are usable to form an axial pivotal member, e.g. similar to 17T) of figures 33 to 40. Mechanical arms (l4Q) may incorporated with hinges (25Q) engaged to a membrane (ISQ) for support around the membrane's circumference to aid engagement with an irregular circumference of a wall portion (4, 5) and to aid urging the expansion or coflapse of a membrane.

[0125] The folding of the membrane (ISQ, 15R), which may also he made of elastic material that can expand, provides increased enlargement capabilities compared to conventionally wrapping a single elastically expandable layer about a shaft. Shafts (6Q, 6k) may be solid or, as shown, may have an internal passage usable for an internal pass through shaft and/or fluid communication to operate a membrane (15Q, 15k), valve, motor, or other fluid device. Axial pivotal members have a deployment diameter (53) and associated circumference, which may be irregular as shown, and an effective diameter or circumference after expansions that may or may not (ISA of figure 4) be proximally circular.

[0126] A membrane (1 SQ. 15R) may be arranged to form a bag or packer-like shape similar to (ISA), (1ST). (ISU) of Figures 3,3-40 and 55, respectively, or a conical shaped single continuous pedal basket (22Q, 22R); or conical wrap similar to figure (22N) of Figures 29 and 30, wherein the folding or overlapping of material or pedals lessens with axial distance from the plan view slices shown in Figures 28,3] and 32 until a single layer without folding or overlap exists in a conical shape. for bag or packer shaped membranes the progression from folding to single layer about the associated shaft occurs on both ends of the Figure 31 and 31 plan slice views. For conical shapes, similar to (22N) of Figures 29 and 30, the transition from folding or overlapping occurs on only one axial side of said plan view slices.

[0127] Accordingly, any form of cellular, envelope, bag or packer shapes may be formed to hold fluids within and separate cells forming a packer or single cell forming a packer. Conical shapes may be formed to hold fluids or debris in one axial direction with significantly tess fluid or debris holding capacity in the other.

[0128] Because various membranes embodiments of the present invention need not be made of conventional inflatable elastomeric material, designed to hold a stationary position across a large differential pressure, but rather, in various instances, embodiments may be formed with relatively thin material capable of being folded.

wherein the present invention is capable of a larger expansion diameter to deployment diameter (58) ratio, compared to conventional apparatuses. For example (e.g.), a conventional 2.125 inch deployment diameter inflatable is capable of expanding to a 6.5 inch diameter as shown in Figure 2A, which results in a ratio of approximately 6.5/2.125 = +7-3.1. The folded membranes (15R, l5Q) with a similar 2.125 inch deployment diameter may be unfolded to a circumference equal to a diameter of 8.5 inches, hence the ratio before any expansion occurs is 8.5/2.125 = 4.

With similar materials to those used in conventional inflatables. the expansion diameter to deployment diameter ration will always be greater for the present invention, because the purpose of the present invention is different to that of a conventional inflatable, which is placed in an unsupported stationaiy position using slips against the well bore to hold large differential pressures across the membrane, wherein the present invention traverses along the erratic axis of well bore, and wherein a desirable function is to defoim according to the circumferential shape of the welibore. Conventional inflatables seek to cause friction with the well bore, whereas the present invention seeks to place a lower differential pressure membrane across the well bore and reduce frictional constraints to allow it to move through substantially differing circumferences using, e.g., fluid drive, engaged selective pressure valves and/or wheels to facilitate piloting of the tool string.

[0129] While radial folding is shown and explained relative to an expanded to deployment diameter ratio, folding may not be used in various embodiments while other embodiments may fold axially. wherein a long axial length membrane folded in two to, e.g. minimize the effective deployment diameter may extend radially outward significantly beyond the deployment diameter, dependent upon the axial length of a fold; hence, the expansion to deployment ratio capabilities, using folding, are capable of expanding from the conventional coiled string smallest deployment diameter to the inside diameter of the largest casing, simply be making the axial length of the membrane longer.

[0130] Indeed, the present invention differs significantly from much of prior art, where maintaining station with a pressure differential is the primary desired feature.

whereas the present invention is usable for access and passage through a well bores walls, whereby differentiating interoperability with a well bore, compared to prior art, may be illustrated by, e.g., an ability to increase the efficiency of crushing pistons traversing a tortuous well bore to deform tubing using differential pressure and the elements of a geologic time frame to abandon a well bore, wherein the present invention is abile to focus more on crushing with less on the frictional for a crushing piston passing through a well bore. One of the various objectives of the present invention is to reduce friction and improve movement and, e.g., improve crushing above what might otherwise be expected through a tortuous passageway by adding the interoperability of. e.g. skates or fluid lubncation from permeable membranes (27T of Figures 33 to 38), after which the expanded membrane (l5Q, 15R) may be used to support cement, wherein it is itself supported by the debris that it has crushed. In instances where support is desired, e.g. when placing a settable cement like material to seal a well bore, the present invention may, e.g., be rested upon debris within the wellbore. Additionally interoperability may be added with inclusion of positive displacement valves (1 1A of Figure 4) used within a shaft and membrane to fill said membrane and further provide fluid lubrication (27T of Figures 33 to 38) while maintaining its expansion and/or bleeding-off trapped pressure for passing through restrictions or trapped pressure resisting the crushing of well components, whereby bleeding off to reduce friction operates a momentum vibrator (l2A of Figure 4). As objects in motion tend to stay in motion, momentum vibrators may significantly increase the crushing ability of an embodiment.

[0131] Operability between. e.g.. wheeled mechanical linkages or skates (7T1 and 7T3 26T1 and 26T2 of Figure 33), membranes (15R. 15Q), pedal baskets (22P, 22N of Figures 28 to 30) and an associated plurality of shafts and/or other axial pivotal members usable to pilot, orient, place, retrieve, dispose, initiate, connect and/or other provide functions associated with access or passage through a well bore using a coiled string compatible connector, may simp'y be referred to as interoperability beteween a circumferential adapatable appararatus (2), an associated downhole devices t'3), and the associated tool string (8) when traversing substantially differing well bore circumferences.

[0132] Figure 33 shows an elevation view while Figures 34 to 41 show various other views of a method (1) embodiment (iT) and apparatus (2) embodiment (2T) usable with a tool string (8) embodiment (8T) and downhole device 3).

[0133] The tool string may be deployed before or after actuation of springs (23T1-23T4) used to store energy within the tool string, which may occur at surface or within a well bore. Any downhole prior art or conventional actuator device (42), e.g. an electric mechanism, timer mechanism, slickline pump, hydrostatic pressure actuator or small explosive charge actuator between the coiled string compatible connector (17) and circumferential adaptable apparatus (2T), at the lower end of the string (8), is usable to actuate the tool string (ST) by axially compressing shafts (6T1-6T9) disposed about and along a central shaft (6T10) against said springs (23Tl-23T4) to selectively trap energy within the apparatus (2T) for axial pivotal member (7T1-7T3) expansion. Any form of slips or other positional device may be used to retain the selective axial combined length of shafts 6Tl-6T9) and springs (23T1-23T4) to store energy along the central shaft (6T10) associated, with the level of stored energy usable for initiating expansion and resisting collapse of the axial pivotal members (7T1-7T3).

[0134] Interoperability between a plurality of shafts (OTl-6T10) with inteniiediate springs (23T1-23T4) operable between upper 26Tl) and lower 26T3) skates and intermediate axial pivotal packer (7T2) to pilot between the substantially differing circumferences of the, e.g., 2 7/8 inch outside diameter 8.6 pounds per foot production tubing with an inside drift diameter of 2.165 inches within a casing bore (5T) of. e.g., 8.535 inches inside diameter of an outside diameter of 9 5/8 inche casing, associated with 53.5 pound per foot density; wherein the inside diameter and associated circumference of the casing (9T2) is deformed (4T), and whereby the apparatus's (2T) has, e.g., a2.i inch coflapsed deployment diameter to traverse the expandable packer 7T2) between the 2.165 inch and 8.535 inch diameters as well as the casing deformities using the skates (7T1, 7T3 or 26T1, 26T2) to pilot the packer (7T2) with string tension andlor pressure applied (31) to the packer from the tubing against any pressure underneath the packer. The apparatus (2T) deployed with, e.g., the coiled string connector at its upper end and/or pressure applied through the tubing to the upper end of the packer (7T2), carries a downhole device (3T) at is lower end for access and passage through the substantiafly differng circumferences (iT).

[01351 The lower end downhole device (3T) may be any usable downhole device that is deployable with a shaft (6T9) connector and/or upper end coiled string connector, for example (e.g.) a perforating or expthsive sculpting charge, logging tool, actuating tool or motor, boring bit or abrasive device, wedge. Various arrangement may be used, e.g.. the central shaft (6Tl 0) may rotate with bearings within encompassing housing shafts (6T1-6T9) to turn a boring bit (e.g. 3T) operated with, e.g., a 1.68 inch outside diameter fluid motor above the apparatus (2T) held substantially stationary by the skates (26T1, 26T2) also used to orient a hole finding device (e.g. 3T) and lower end boring bit. If a rotary cable tool positive displace hydraulic motor of the present inventor is used the packer (7T2) may be used to route circulated fluids upward through the annulus after exiting the lower end of the 2 7/8 inch tubing.

[0136] Interoperability may be enhanced with orifices (28) permeable membranes 27T) portions andlor valves (11, 1 iT 1, 1 1T2) operable with the primary membrane (1ST) to allow fluid pumped into and exhausted from the well or membrane to lubricate traversing engagement between the axial pivotal member (7T2) and the dissimfiar passageway walls (9Th 9T2, 4T, ST), wherein upper (22T1) and lower (22T2) end pedal baskets may be used to flexibly protect the membrane when traversing through the well bore (10). The primary membrane (1ST) and associated pedal baskets (22T1, 22T2) may be further reinforced by hinged arms (14T3) about their engagement circumference, wherein fluid pressure against the membrane, axial movement of the internal shaft (6T10) andlor wedging of the upper inverted pedal basket (22T1) against, e.g., the 2 7/8" tubing or wall portion (4T) may be used to wedge and/or inflate or deflate the membrane (1ST).

[0137] The apparatus (2T) and lower end downhole device (3T) may be deployed and retrieved with a coiled or jointed pipe string, but it may also be dropped from a string or surface to, e.g., use fluid pressure above the packer 7T2) with a wedging device (3T) comprising, e.g. another pedal basket or other expandable device suitable for urging or wedging at the lower end, to, in use, attempt to push and defonm walls and/or debris radially outward and/or axially downward independently of a string connection, after which the tools (2T.3T) could be retrieved with a coiled string via a fishing neck. The present invention provides significant benefit by centralizing the tool string to improve the probability of fishing the dropped tool string.

[0138] Referring now to Figures 34. 35 arid 36, which show a plan view with line B-B and an elevation cross section view along line B-B with break lines showing removed portions associated with the Figure 36 isometric view of Figure 35 with portions removed, where detail line C is associated with Figure 37, illustrating a method (IT) and apparatus (2T) usable with a tool string (8) and downhole device 3) for access or passage through a well bore's (JO) dissimilar contiguous passageway walls t9T1, 9T2, 4T, 5T). The circumferential adaptable apparatus (2T) is shown with it lower having passed a damaged wall (4T) and large diameter change of, e.g. a 2 7/8 inch tail pipe (9Tl) axially centralized within a casing (9T2) by, e.g., a production packer.

[0139] Alternatively, the tubing could be laying on the low side of an inclined or horizontal bore, e.g. see Figures 3, whereby the spring (23T4) activated lower skate (7T3) may lift and pilot the tool string over the deformation (4T) until the springs cause the packer (7T2) to further pilot and orient the tool string towards the proximal axis of the well bore until the tool stnng exits the tubing and both skates (7Tl, 7T3) and packer t7T2) assisted by springs, string tension and fluid axially pumped within the well bore to pilot the entire assembly within the proximal centre of the well bore as the coiled stnng interacts with the tubing to lift it andlor form a catenary curve with the trailing string as the tool string traverses through the well bore past the deformation UT) to the wells lower end.

[0140] Figures 37 and 37A show magnified detail views within the detail line C of Figure 36 and the detail line M of Figure 37. respectively, of the embodiments (iT, 2T) of Figure 34. The upper end pedal basket (22T1) has orifices (28) to allow fluid pressure from surface to enter the membrane (1ST) through the upper one-way valve (llTl) usable with, e.g., shaft mounted sprngs to fluidly inflate the membrane (l5T) and pump fluids through permeable pores (27T) in the membrane (l5T) to lubricate its circumferential connection with the well bore when pumping and traversing through various circumferences within, thus allowing it to inflate and deflate according the restriction, yet retain the function of a sealed compression piston or movable packer.

[01411 Deforming around restrictions and debris when piloting and traversing through the well bore is aided by mechanical linkages (l4T13) and hinges (25T3) engagements to individual pedals of the basket (22T1). For various embodiments a momentum vibrator (12A of Figure 3) or positive displacement valve (II A of Figure 3) may be added to the arrangement to further enhance interoperability between the tools and the dissimilar passageway walls by controlling fluid pressure with the membrane (15T) andior increasing lubncation about its circumference. In various other embodiments, e.g. one similar to (IX) and (2X) of Figure 42, a small diameter fluid motor, which are conventionally available in, e.g., 1.68 inch outside diameter plurality of shaft arrangements, that may be incorporated with or at an end of the membrane (15T) to power, e.g., a reactive torque tractor to move the tool string along the dissimilar passageway walls using, e.g. the gripping and/or cutting wheel various of the skate (26T1, 26T2) arrangement shown in Figures 38 to 40.

[01421 Referring now to Figures 38, 39 and 40, which show an isometric view of Figure 33 with detail lines D and E and magnified detail views within lines D and E of Figure 38, respectively, illustrating the embodiments (IT, 2T) of Figure 33. The axial length of mechanical linkages (I 4T1 and 14T2, I 4T4 and 14T5) may be varied between the shaft connection and hinged (25T2 and 25T3, 25T10 and 25Th, respectively) connect to the skates (26T1, 26T2, respectively) to accommodate varying diameter ranges and where sufficient space exists within a circumferential adaptable apparatus (2) independent springs may be engaged to each skate to selectively pilot the tool string, wherein a series of spnngs surrounding the central shaft are individually engaged to each skate or smaller diameter spnngs placeable within the radial distances between, e.g.. a central shaft and encompassing or surrounding shaft.

[0143] A deformable packer and wedging axial pivotal member 7T2) is formable with an upper pedal basket (22T1) flexibly hinged (25T5, 25T6) to a shaft (6T4) and mechanical linkage (14T3) supporting and flexibly hinged (25Tl3) to the upper end of a deformable membrane (15T) engagable with the wall portions (9T1, 9T2), wherein permeable pores (27T) allow fluid lubrication of the engagement when traversing the dissimilar contiguous passageway (9T, 9T, 9T2). The membrane's (1ST) lower end is flexibly hinged (2517) with a mechanical linkage (14T3) to the lower end pedal basket (22T2) flexibly hinged (25T8) to the shaft (615).

[0144] Upper and lower springs (23T2. 2313) act against associated upper and lower wedge (37T], 37T2) shafts encompassing the central shaft (6T10) to urge the expansion of the upper and lower pedal baskets (22Tl, 22T2) to initiate fluid filling of the membrane (151) through the one way valve (1ITI) and orifices (28) in the upper inverted basket (22T1). Pores (27T) in the membrane may be of a one-way flow variety using, e.g., the flap and orifice (28) example valve (II) shown or open to allow initial filling of the membrane (1ST). After initial spring actuated expansion and fluid filling of the membrane (15T) further fluid filling is possible by surface fluid injection (31) through the orifices (28) in the upper basket (22Ti) and upper one way valve (1 ITI), wherein fluid exiting the lower one way valve (11T2) acts against the lower basket (22T2) to further expand the membrane (1ST) by acting against and expanding the lower basket (22T2).

[0145] Collapse of the axial pivot member (7T2) may be accomplished by, e.g,, stopping injection of fluid (31) and tensioning the string to puil the upper basket (22T1) into the lower end of the tubing (9T1) so as to compress the springs and force fluid from the membrane (151), wherein fluid may be expelled from the membrane through the pores (27T) and between pedals as the lower basket (22T2) is collapsed. If fluid filling from the lower end is not a concern, orifices may be used instead of a one way valve (1112).

[0146] Any variation of wheel(s) may be engaged to a skate (26) or axial pivotal member (7) to. e.g., reduce friction, pilot the tool, prevent rotation of a shaft, and/or cut a well bore's walls (9), for example (26AA, 26AB, 26AC) of Figures 43 to 48. As wheels type and diameter will affect the circumferential adaptable apparatus (2T) deployment diameter as shown in Figure 39, their purpose and associated shape should be considered, wherein selective adjustment of mechanical arm (14) length and actuator, e.g. spring force, may be matched to the wheel and purpose.

[0147] Figure 41 shows an elevation view of a mechanical linkage arm (14) shaped (29) embodiment (29T1) usab'e with various embodiments including that of Figures 33 to 40, wherein a lower end cam lilce shape (29T1) is used to support the arm against a central shaft (e.g. 6T10 of Figures 33 to 40). Interoperability between tools of the tool string (8T) may be enhance by selectively placing shaped (29) linkages, 111cc the cam embodiment (29T1). wherein by placing a cam shape, e.g.. at the upper binges (25T]. 25T4) tends to aid retraction of arms (14) with string/shaft tension and aid extension with shaft compression. whereas placing the cam shape on the lower hinges (25T2. 25T5) tends to aid extension of the arms (14) with string/shaft tension and aid retraction with shaft compression, wherein the shape may also be used to limit expansion and retraction of the arms (14).

[0148] As illustrated in the examp]e tool string (ST), various method (1) and apparatus (2) embodiments of the present invention are combinable in a variety of ways to meet the needs of access and passage through damaged and/or restricted portions of a well bore, wherein various forms of pedal baskets, membranes, slcates, valves, hinges.

springs or any other downhole coiled string compatible mechanism oriented and arranged at surface and downhole are usable to selectively pilot any suitable downhole device (3T).

[0149] Figures 42, 51 to 53 and 55 to 56 are diagrammatic illustrations of various methods of the present invention, wherein the associated apparatuses of each Figure may include any apparatus embodiment of the present invention in addition to the depicted apparatuses.

[0150] Referring now to Figure 42, which depicts a diagrammatic elevation view of a slice through a well bore (10), illustrating a method (I) embodiment (ix) and apparatus (2) embodiment (2X) usable with a tool string (8) embodiment (8X) and downhole device (3) for access or passage through a well bore's dissimilar contiguous passageway walls (9X) comprising wall portions (4X, 5X). The tool string (8X) is usable to, e.g. mill the dissimilar wall portion (4X) by placing any variation of cutting wheel arrangement, e.g. (26AC) and (26AB) of Figures 43-44 and Figures 45-46, respectively, and using a hydrodynarnic fluid bearing milling motor described in GB2486591 of the present inventor to rotate the axial pivotal member 7X2) comprising, e.g., carbide encrusted basket pedals with overlapping pedals arranged for the direction of rotation and operated by power fluid passing through the top inverted pedal basket orifices (28) to turn a rotating stator motor shaft (6X3) secured to the cutting carbide encrusted baskets (7X2) rotated about a central shaft (6X5) held substantially stationary by the axial pivotal cutting skate members (7X1, 7X3).

[01511 As fluid is pumped (31) through the orifices (28) and between the rotatable stator shaft's (6X3) hydrodynamic surface and the central substantially stationary shaft (6X5), the power fluid (3]) rotates the carbide baskets (7X2) to mill the dissimilar wall portion (4X) which may also be axially cut by the skates (7Xl, 7X3) when the tool string (8X) is raised and lowered with string (8) tension. The shape of the opposing baskets, their flexible pedal nature and string tension when moving the rotating baskets across the dissimilar wall portion (4X) gradually grinds and/or smooth's the disfigured or restricted well bore 00) to allow passage of other tools and strings. The lower end downhole device (3X) may, e.g., be a calliper tool used to measure the well bore's (10) walls (9).

[01521 The tool string (8X) is also useable with a conventional electric or fluid motor forming the shaft (6X3) instead of a hydrodynamic fluid bearing motor with a lower end rotary downhole device (3X), wherein the upper and lower skate axial pivotal members (7X1, 7X3) hole thc conventional motor's housing substantially station while it rotates the bit, brush, grinder, jetting tool using fluid funnelled from the axial pivotal member (7X2), or any other suitable rotary tool.

[0153] Figures 43 and 44, Figures 45 and 46. and Figures 47 and 48, illustrate mechanical linkage (14) embodiments (I 4AC, I 4AB, 14AA, respectively) with wheeled (26) embodiments (26AC, 26AB I and 26AB2, 26AA, respectively) and hinged (25) embodiments (25ACi and 25AC2, 25AB1 and 25AB2, 25AA1 and 25AA2, respectively) usable with various other embodiments of the present invention.

Shafts (6X I -6X4) encompass or surround central shaft (6X5) which may be substantially stationary or rotatable during deployment and/or use, wherein tensioning and relaxing of tension within the shaft (6X5) extends and retracts the axial pivotal members (7X1-7X3) by disposing the shafts (6X1-6X4) along the central shaft to urge expansion and retraction of the members. Various actuators may be used to both extend and retract the members by tensioning and removing tension from the central shaft (6X5). Wheel and skate configuration profiles, including the number and orientation of wheels and skates, are usable to cut and/or function as an anti-rotation device to prevent axial rotation of a connected shaft.

Depending upon the application a varety of axial cutting wheel configures may be used to deform a well bore wall through a relatively low frictional cutting action, wherein repeated axial movement of the tool string (8) within the well bore tends to progressively weaken and/or shred the affected wall portion.

[0154] The shape of the wheeled components and associated linkage arms for extension and retractions are generally configurable to fit within the minimum diameters of a wall bore, wherein a single skate may be used with the deployment shaft engaging a well, or two skates may be used to cause helical turning about, e.g. a ball joint shaft or other anti-rotation mechanism, or three or more skates may be used to provide, e.g., anti -rotati on.

[0155] Any embodiment of the present invention may use bearings, races, greases or other friction reducing devices to, e.g., improve hinged connections (25), rotating connections, radially disposed connections, axially disposed connections, and/or or wheeled (26) and mechanical linkages.

[0156] Refening now to Figures 49 and 50, which depict a diagrammatic isometric view of a prior art shot gun and a diagrammatic isometric view of apparatus for explosively crushing downhole well bore components, respectively, of the present inventor described in GB2486591. whereby the present invention provides significant improvement over the explosive deformation of downhole conduit walls by providing pilotable tool strings embodiments with shock absorbing and focusing capabilities. Similar to a prior art shot gun (51) which uses an explosive chamber (52) to propcl objects from a barrcl (53), a well borc's (10) walls (9) may bc used as a barrel from which an explosive arrangement (55) may be used to axially propel at least part of various wall portions (4, 5) usiiig an apparatus similar to a shotgun shell wad (56) with a pressure relief orifice 57). Axial pivotal pedal baskets are similar to a shotgun shell wad for propelling and/or wedging open of wall portions (4, 5), wherein an inverted pedal basket is usable to absorb the axial fluid hammer effect of using explosives within a well bore as well as focusing an explosive fluid hammer in a particular axial direction like a shaped charge (40 of Figure 22).

[0157] Figures 51 and 52 show diagrammatic elevation views of slices through a well bore (10), illustrating method (1) embodiments (1Y, 1W, respectively) and apparatus (2) embodiments (Ti, 2W, respectively) usable with a tool string (8) embodiment (8Y, 8W, respectively) and downhole device (3) comprising an explosive (3Y, 3W) for cutting, sculpting and/or wedging open a dissimilar passageway wall portion (4Y, 4W) to provide access or passage through a well bore's dissimilar contiguous passageway walls (9Y. 9W), wherein an axial pivotal conical members (7Y). e.g. a pedal basket or cone wrap, is used to act against the axially above fluid colunm to limit lifting of the tool string (8Y) when an explosive (3Y) is fired and inverted axial pivotal conical components (7Y3. 7W1-7W2), e.g. pedal baskets or conical wraps, used to focus a lower end fired explosive (3Y, 3W) axially downward.

[0158] Slips engaged to the axial pivotal members (7Y2, 7W3) to engage the tools strings (8Y. 8W) to the well bore walls, hence they may function as a bridge plug (35Yi, 35Y2) during firing of the explosives. For tool string (8Y) the opposing conical axial pivotal members (7Y I, 7Y3) may be mechanically linked to extend the slips to reduce the probability of upward moment of the tools string (SY) and avoid application of a fluid hammer effect to well equipment above the tool string or bird nesting of, e.g., a slickline string, wherein axial tension on the string to a shaft (6Y I) passing through the upper conical funnel member (7Y1) may be used to release both the slips (7Y2) and lower conical funnel member (7Y3) and retract the upper conical funnel member (7Y1) with, e.g., retraction of an extending wedge (37T1 and 37T2 of Figures 34 to 40).

[0159] Upward movement of the tool string (8W) may be limited by, e.g,, placing slip like profiles on the pedals of the inverted conical pedal basket or surface of the conical membrane that are expanded by the fluid hammer associated with igniting the explosive (3W) to engage the conical forms (7W1, 7W2) and associated securing slips to the well bore (10) walls (9), wherein orifices (28) are provided to release excessive explosive pressures that may damage the axial pivotal members (7W 1, 7W2). Initially the lower slips may be set and the cones expanded with upward axial movement of the central shaft (6W1), wherein after firing of the explosive charge (3W), the conical funnel slip members (7W1, 7W2) may be retracted by tensioning upon the sulTounding shaft (6W2) engaged via a flexible hinge to the members (7W 1. 7W2) and associated shaft (6W3) to release the lower slips member (7W3).

[0160] Additionally to remove the possibility of creating a birds nest of wire with, e.g., a slickline or dectric line tool strings (8Y, SW), the apparatuses (2Y. 2W) may be deployed with the deployment strings (8) detached and a timer used for firing the explosives (3Y, 3W). after which a retrieval string may be deployed to engage the upper end shaft andlor connection to pull the shock absorbing and focusing apparatuses (2Y. 2W). Removing the deployment string aho allows placement of, e.g., an inflatable packer or packer embodiment of the present invention above the apparatuses (2Y, 2W) to provide a backstop or secondary assurance that they will not be propelled uphole by an explosion downhole.

[0161] To provide passage through the restricted wall portion (4Y) an explosive device (3Y) is usable to cut or sculpt the wall with, e.g. (Ill, i I, Ii) and (IM) of Figures 14- 19 and Figure 23, to provide additional space between the resicted circumferential walls. The method (1W) may use a conical axial pivotal member (7W4) to wedge the deformation and/or debris wall portion (4W) open to create more space between the restricted circumferential walls for access or passage, wherein the conical funnel wedge (7W4) is separable from the tool string (.8W) to move axially downward and focus the explosion caused fluid hammer radially outward as the cone expands. A fishing engagement may be provided with the detachable wedge or it may be speared for retrieval. Alternatively it may be explosively perforated, milled and/or pushed downhole or destroyed. Additionally, method (1W) may follow method (IY) and be followed by method (IY) or any other method embodiment to cut, sculpt and/or wedge open a wall portion, debns and/or debris from cutting, sculpting or wedging wall portions radially outward to form an larger effective pass through diameter.

[0162] Referring now to Figure 53 which illustrates a diagrammatic. elevation view of a slice through a well bore (10) method (1) embodiment (1V) with apparatus (2) embodiment (2V), and Figure 54, which shows an isometric view of a logging tool embodiment (lAD) sensor/transmitter (59) in a shock absorbing housing mechanical linkage (14) embodiment (I4AD) using springs 23AD) to provide shock absorbing cushion to movements from. e.g., explosive fluid hammers, wherein the embodiments are usable for providing a logging well bore image to provide empirical measurement data for access or passage through a well bore's dissimilar contiguous passageway walls (9V) during various operations including passage and cutting or explosive operations that may cause significant shock or vibration.

[0163] A tool string (8) embodiment (8V) may use various mechanical arm deployed axial pivotal members (7V1-7V3). wherein a logging (59) downhole device (3V) may be engaged to an expandable pivotal component (7V2) to provide, e.g., inclination logging information associated with tool string (8V) data collection transmitted through sonic pulses within, e.g., the casing wall where it may be collected from the wellhead in a similar manner described by the present inventor in GB2483675, wherein an axial pivotal member is usable to place the transmitter sensor on the casing while piloting a tool string (8V) through the well bores walls. As the axis within a dissimilar passageway walls (9) may be erratic the tool string (8V) may have a ball joint, knuckle joint or flexible joint (6V) to provide inclination logging data between upper (6V3) and lower (6V4) shafts as well as piloting of the tool string around restrictions or through wall portion enlargements (4V).

[0164] Data may be transmitted through electric line or fluid pulses within the fluid column within the well bore (10) in various embodiments. Data transmittal is however complicated during slickline rotary cable tool positive fluid displacement motor operations, wherein transmittal through the well bore's waIls (9) provides an altemative, since slicldine has not electrical core and upward pulses with small diameter wireline tools are more difficult.

[0165] Accordingly a logging downhole tool (3V, 3AD) formed with. e.g., a mechanical linkage (I4AD) may be engaged to arms (l4V) via flexible hinged connections (25AD I, 25AD2) deployed via, e.g., tool stithig weight, string tension, springs andlor hydraulic actuator interoperability with shafts (6V3), (6V7) and (6V8) to maintain contact with the well bore walls WV) to, e.g., provide anti-rotation functionality and perform logging operations to. in use, collect/transmit data through a sensor/transponder (59) collecting or transmitting data through the well bore walls (9V) more or less on a continuous basis via battery power supplemented by a fluid turbine electrical generation tool within a tool string. For example, the circumferential adaptable logging apparatus (2V) may be combined with the boring apparatus (1X of Figure 42) to allow continual monitoring of slickline boring data, such as stick slip and vibrational information that could limit the life of the tool string (8X, 8V).

[0166] Alternatively, axial pivotal member (7V I) could be a combined anti-rotation conical funnel for directing fluids shaft (6V7) comprising, e.g., a batter with supplemental fluid turbine generator with fluid continuing through shaft (6V8) and (6Y3) comprising, e.g., logging apparatus connected with the sensor (3V1), connected via a directional control joint (I 6V) to a fluid motor shaft (6V4) driving shaft (6V5) through anti-rotation skates (7V3) to a rotary bit stick/slip inhibitor shaft (6V6) turning a rotary bit (3V2), wherein the efficiency the vibration of the entire tool string (8V) as well as directional control could be monitored continuously from the surface wellhead through pulses sent through the casing via a transmitter's (59) engagement with the casing (9Y).

[0167] Figure 55 depicts a diagrammatic elevation view of a slice through a well bore (10), illustrating a method (1) embodiment (lU) and apparatus (2) embodiment (2U) usable with a tool string (8) embodiment (8U) and downhole device (3) for access or passage through a well bore's dissimilar contiguous passageway walls (9U). The movement of fluid filled single cell or multi-cell membrane balloons, bags or packers may be subject to significant frictional forces across substantially differing circumferences as the membrane conforms to the dissimilar walls (915) and/or debris (18).

[0168] A membrane is usable as a packer (34U) and/or bndge plug (35U) and may be inflated in various conventional ways similar to those used to fill inflatable packers, which can include, e.g., a slickline pump. Once filled, a fluid tilled membrane may be traversed through dissimilar walls (9U) using a hole tinder comprising, e.g., a tapered bull nose (3U2) engaged to a shaft (6U5) with a flexible skate (7U2) allowing tiuctuarions between fully expanded and less than ful]y expanded to facilitate angular variation (61) of the shaft (6U5) and bullnose (3U2) from the proximal axis of the passageway (915), wherein the inflated membrane may, e.g., be pushed with surface fluid pressure (31) and vibrated through the passageway using a momentum vibrator (12U).

[0169] The upper valve (1 1UI) maybe omitted to allow higher fluid differential pressure to follow its own chosen path, or to allow higher differentia' pressure trapped below to dominate with (lIUl) placed as shown above upper orifice (28) in shaft (6U1) or to allow higher differential pressure from above to dominate with the one-way valve (IIUI) placed immediately above lower orifice (28) in shaft (6U4), wherein fluid passing between the upper, lower and intermediate (28 in shaft 6W) orifices operate the positive displacement fluid relief valve (.1 1V2) and momentum vibrator (12U) comprising, e.g., a helical rotor shaft (6U2) and stator shaft (6U3). Interoperability between the membrane (15U). valves (I IUI and/or 11112) and momentum valve (I 2U) allow higher pressure to move to lower pressures, for example, pressure from orifice 28) in shaft (6U4) may fill the membrane through the intermediate orifice (28) in shaft (6U1) or exit the upper orifice (28) in shaft (6U1) above valve (liUl).

[0170] If pressure from above (31) overpressures the membrane (15U) by either forcing it downward against a restraining force, or by filling it if the valve (11111) is absent, fluid pressure may exit the membrane (15U) and exit below or above the membrane, wherein any transfer of fluid due to a differential pressure difference operate the momentum vibrator to cause vibration and angular variation (6!) to vibrate the membrane and shaft while increasing and decreasing the membrane interna' pressure to cause it to move in the desired direction (31).

[0171] Vibration of a piston packer is especially useful in the crushing of conduits and other well equipment downhole, as descnbed in patent GB2471760B and priority patent application GB2484166A of the present inventor, wherein the downhole device (3U) may be, e.g., a connector to the conduit being crushed.

[0172] Accordingly, the present invention provides significant benefit over GB2471760B and 0B2484166A by providing a means of reducing the resistance to crushing through, e.g., vibration and piloting of a packer used as a piston to crush downhole well components through dissimilar piston passageway's walls of substantially differing circumference, thereby improving the ability to enable or provide cap rock restoration using the method (I) and apparatus (2) embodiments of the present invention.

[0173] Figure 56 depicts a diagrammatic elevation view of a slice through a well bore (10), illustrating a method (1) embodiment (1Z) and apparatus (2) embodiment (2Z) usable with a tool string (8) embodiment (8Z) and downhole device (3Z) for access or passage through a well bore's dissimilar contiguous passageway walls (9Z]), wherein a restriction (4Z) prevents passage of a prior art crushing piston, unsuited for piloting the substantially differing circumferences of the well bore's (10) walls (9Z1), and the apparatus (2Z) with lower end hole finder (3Z) rigid or flexible builnose suited to crushing tubing (9Z2) debris (18) within the casing (9Z1).

[01741 The circumferential adaptable apparatus uses offsetting conical axial pivotal members (7Z1, 7Z3) to form two pistons with an intermediate skate stabilizer (7Z2) and intermediate spring like devices (23Z], 23Z2) usable to transfer energy between the pistons as the apparatus (2Z) passes through the restriction (4Z), wherein the crushing force associated with the larger diameter of the passage 9Z) is maintained.

Maintenance of the pressure against the larger diameter and associated force associated with the area of the larger circumference as the tool passes through the smaller diameter is maintained is provided by a passageway (24) through shafts which opens the nearest orifice (28) when a axial pivotal piston member is collapsed and closes it when it expands.

[01751 Collapsing the lower piston (7Z3) against the restnction (4Z) opens the lower orifice (28) valve (1 1Z2) and bleeds off any trapped pressure between the pistons through the intermediate orifice that remains open and the upper pistons area controls the force applied. As the lower piston exits the restriction (4Z) and expands the lower orifice (28) closes and crushing continues until the upper piston (7Zl) encounters the restriction and opens its valve (liZi) to allow pressure against the lower piston to pull the apparatus (2Z) through the restriction i4Z).

[01761 Valves (e.g. I IZI-11Z2) that selectively open and close according to the state of an expandable and collapsible axial pivotal member (7) may be formed within the various embodiments of the present invention by the disposition of various shafts within the plurality of shafts used by an apparatus (2). Spring like mechanisms (e.g. 23Z1, 23Z2) may be used to trap energy within an apparatus (e.g. 2Z) using their spring like their nature and the disposition of a plurality of shafts (e.g. 6Z1-6Z5) relative to the spring like mechanism, wherein energy may be placed within the shaft and spring like arrangement at surface or within a subterranean well bore using a downhole actuating device.

[0177] Axial and/or radial movement of a pivotal axial member (e.g. 7Z1-7Z3) may act against the plurality of shafts and spring like arrangement to, e.g., align orifices (e.g. 28 of Figure 56) with a central fluid passageway through a central shaft (e.g. 6Z1) and form valves (e.g. 11ZI, I lZ2) to transmit fluid between pressure differentials through. about and between sealing axial pivotal members (e.g. 7Z1. 7Z3) to, e.g..

selectively apply pressure to plurality of crushing pistons (7Zl, 7Z3) to maximize the crushing force against debris (18, 9Z2) by selectively applying a pressure differential across the largest area (IZ).

[0178] While the restriction shown (4Z) is substantial, it also represents frictionally obstructive resistance to crushing from, e.g., a relatively consistent well bore wall with regular internal gaps associated with, e.g., conventional buttress casing couplings, upon which a piston might catch hold of or lose its seal, thus reducing the crushing force. Providing pistons energised by spring like mechanisms (23Z1, 23Z2) with valves (liZi, 11Z2, 11UI-11U2 of Figure 55), momentum vibrators (l2U of Figure 55), flexiblejoints (i6V of Figure 53), skates (26T1-26T2 of Figures 33-40) and/or other embodiments arranged to expand, seal and contract selectively according to well bore walls (9Z1) provides significant benefit over prior art by maximizing the forces and compression of downhole debris (18, 9Z2) when fornñng spaces for placement of a settable sealing material.

[0179] Additionally. the ability to place fluids through a central passage within a shaft or between shafts provides both momentum vibrate dunng crushing and forms a motor to provide, e.g., a reactive torque tractor within shaft (6Z2) to aid crushing of, e.g., production tubing (9Z2) to form debds (18) upon which a settable sealing material can be placed to abandon a well, and wherein axial pivotal member cutting wheel skates (26AC, 26AB, 26AA of Figures 43 to 48) and spring like mechanisms may be used with said pivotal tractor to aid crushing. The addition of vibration and/or the pull of a reactive torque tractor operated by, e.g., a positive displacement valve (i 1U2 of Figure 53) may provide significant benefit to crushing when combined with differendal pressure from the fluid column because, according to the laws of physics. objects that are at rest tend to stay at rest and objects in motion tend to stay in motion, hence providing a significant benefit over pnor art.

[0180] Referring now to Figures 57 to 64 which illustrate various views of method (1) embodiment (IAE) and apparatus t2) embodiment (2AE) usable with a tool string (8) embodiment (8AE) and downhole device (3) for access or passage through a well bore's dissimilar contiguous passageway walls (9AE), wherein turbine blade (62) driven cutting (I3AE) downhole devices (3AE) are usable to deform through cutting, milling or abrading a deformed wall portion (4AE) with a substantially differing circumference form an adjacent waH portion (5AE).

[0181] A series of shafts (6AE2-6AEII) suround and encompass various lengths of a central shaft (6AE 1) with inteirnediate axial pivotal members (7 AE 1 -7AE3) usable to operate the tool string (8AE) and downhole devices (3AE) comprising, e.g., cutting, brushing, milling or other abrasive outer circumference rings with offsetting turbine blade profiles (62) on the inside circumference of the rotating downhole device 3AE) cutters (13), wherein fluid (31) pumped from surface through the dissimilar passageway walls (9AE) is funnelled by a conical pedal basket (22AE) in between turbine profiles (62) and central shaft (6AE) to rotate the cutting (113) tools and mill or abrade a wall portion (4AE) with a substantially differing circumference than adjoining wall portions (SAE) of the weR bore's (10) dissimilar passageway walls (9AEI, 9AE2).

[0182] Upper (26AE1) and lower (26AE2) anti-rotational skates (26) are deployed via flexible hinge (25AE1-25AE5) engagement to associated shafts (6AE2-6AE3, 6AE8-6AE9) actuated with springs (23AE1, 23AE2) to substantially prevent rotation of the central shaft (6AE1) at shafts (6AE3. 6AE9) opposite sliding spring actuation shafts (6AE2, 6AES), wherein said anti-rotation skates are usable across substantially differing circumferences. While opposing turbine blades (62) are shown between cutting ring (3ADI) and an adjacent cutting ring (3AE2) in Figure 64 to illustrate the need to direct fluid (31) in one direction to turn a turbine blade shaped to direct fluid flow in a different direction, which is usable for various purposes, the torque and speed capability of the turbine blades may be increased significantly by fixing turbine blades to the central shaft held substantially stationary by anti-rotation skates (26) to direct fluid flow (31) necessary to rotation the cutting rings (3AE) by fluid force exerted against their associated rotatable turbine blades, wherein the stalling of a single ring does not stop fluid flow past nor rotation of another ring. Additionally, to improve the anti-rotation properties of the tool string (SAE) the profiles place don the central shaft (GAEI) may be used to direct the rotation of one ring (6AE1) in an opposite rotation to another ring (6AE2), wherein the fluid profiles of the central shaft would occur through passageways of an intervening enlarged shaft portion acting as a thrust bearing between cutting rings (3AE) or turbine profiles covered by an thrust bearing shaft (6AEI 1) between the cutting ring (3AEI, 3AE2) downhole tools (3) and/or shafts they may thrust against.

[0183] Figures 57 and 58 show a plan view with line G-G and an elevation slice through line G-G of Figure 57 with detail line H associated with Figure 59, depicting method (IAE) and apparatus (2AE) within dissimilar contiguous passageway walls (9AE) with a break line illustrating a removed section, wherein other embodiments may be placed within the removed section, above and/or below the tool string (8AE). The fluid driven tool string (8AE) is deployable and operable using, e.g., slickline which does have the capacity to circulate fluid, since it lacks a central fluid passageway, wherein fluid (31) may be pumped through the tubing (9AE2). e.g. 5 1/2 inch outside diameter, within casing (9AEI), e.g. 9 5/8 inch casing, and captured by a conical funnel (22AE) axial pivotal member (7AE2) to operate a series of rotatable cutting proffle downhole devices (3AE).

[0184] Fluid flow (31) through the upper end well bore (10) walls (9AE1, 9AE2) will pass the non-sealing anti-rotation axial pivotal member (7AE1) and be captured by the packer (34AE) sealing conical funnel (22AE) axial pivotal member (7AE2) to exit orifices (28) at its lower end to enter the space between the central shaft (6AEi) and the turbine blade (62) rotated cutting (13) rings (3AEI, 3AE2) or any other axial length or shape of rotatable downholc device (3AE) with an internal circumferential turbine blade arrangement (62), wherein fluid exit orifices (28) in the lower end shaft (6AE6) to progress down the well bore walls (SAE, 9AE2).

[0185] Figures 59 and 60 show magnified detail views within line H of Figure 58 and within line J of Figure 59, respectively, showing the fluid flow (31) through the conical funnel's (22AE) lower end orifices (28) between the thrust bearing flexible hinge shaft (6AE5) and central shaft (6AEI) which connects to the turbine blade (62 of Figure 64) passageway between the turbine blade rotatable downhole tool (ME) and the central shaft. Expansion of the conical funnel (22AE) comprises, e.g..

placing a flexible hinge (25AE6) on the shaft (6AE5) axially above the adjacent shaft (6AE1 1) bearing any upward thrust from the rotatable rings (3AE) and engaging the funnel (22AE) flexible hinge (25AE5) to the central shaft (6AE1), wherein axially disposing the hinged (25AE6) shaft (6AE5) relative to the hinge (25AE5) on the central shaft (6AEI) expands and collapsed the funnel (22AE).

Actuation of one shaft relative to the other may occur from various means, whereby a spring like mechanism, e.g. a spring operated expansion joint or hydraulic piston with trapped pressure, may be placed between the hinged shaft (6AE5) and thrust bearing shall (6AEI I), wherein tension on one of a possible plurality of shafts collapses the funnel (22AE) when the tool string (8AE) is retrieved to surface for repair or replacement.

[0186] Referring now to Figures 61, 62 and 63, depicting an isometric cross section projection along line G-G of Figure 57, wherein the tool string (8AE) is unsliced by the cross section, with detail lines K and L associated with Figures 62 and 63, respectively, depicting magnified detail views within lines K and L of Figure 61. As visually illustrated by Figure 6i, the present invention is pilotable through and usable to engage substantially differing circumferences on either side of a drastic frictionally obstructive restricted circular or deformed circumference of a well bore (lO), whereby prior art is primarily concerned with reopening a restricted passageway, keeping an ever increasing circular diameter from the lower end of a well bore (ID) to the upper end. Figure 62 illustrates that the rotatable rings may comprise an rotatable downhole material used in convention practice, such as brush bristles, carbide impregnated surfaces, polycrystalline inserts, hard metals, or knife like profiles arranged in radial, axial, helical or any other pattern corresponding to the direction of rotation, while Figure 63 illustrates how low profile (165) cutting (13) or frictional surfaces may be placed on wheels to enhance the anti-rotation capabilities of a skate (26AE1).

[01871 Additionally, prior art does not exist for performing the tasks described herein. For example, a slickline string may be used to deploy the tool string (8AE) adapted by removing the fluid exhaust orifice shaft (6AE6), placing ports and a passageway through the central shaft (6AE1) to the lower end of the apparatus (2AE) to operate a fluid motor, replacing shaft (6AEIO), to operate a rotary drill bit to first bore through the restriction (4AE) and then polish or brush it with the rotatable turbine rings (3AE), which may be arranged to allow counter rotation to offset the torque of the lower end motor to. in use, provide a significant improvement to rotary cable tool operations.

[0188] Figure 64 shows isometric views of separated cutting surfaces (13) variation of a hydrodynamic fluid bearing shaft arrangement comprising a downhole device of a cutting circumferential adaptable apparatus (2AE) embodiment associated with Figure 62, illustrating how turbine blades (62) may be arranged to rotate one ring (3AEI) relative to another (3AE2) as fluid (31) passes past the turbine blades (62).

Profiles to direct fluids in the appropnate direction to cause opposite rotation (63, 64) may be placed between the cutting rings (3AE1, 3AE2) or rotation of the cutting rings via their turbine blades (62) may occur as friction causes one rings rotation to direct fluid in a direction to rotate an adjacent ring in the same or opposite direction.

As turbine Hades are an art unto themselves, the present invention does not seek to define their rotation various other aspects of their blade shapes and positioning with the various arrangements that may occur, but rather specifies that any arrangement of turbine suitable for the shafts and apparatus in question, may be piloted and operated by the present invention.# [0189] As demonstrated by the description and drawings provided herein, any combination or permeation of the described components of a circumferential adaptable apparatus embodiment (2) may used with the various method embodiments (1). which are also applicable to adaptations of conventional and prior art apparatus to urge access or passage through a subterranean well bore's (10) dissimilar contiguous passageway walls (9); formed by frictionally obstructive debris (18) within or at least a partially restricted circular or deformed circumferences (4, 5) thereof.

[0190] Additionally, while various embodiments of the present invention have been described with emphasis, it should be understood that within the scope of the appended claims, the present invention might be practiced other than as specifically described herein.

[0191] Reference numerals have been incorporated in the claims purely to assist understanding during prosecution.

Claims

<claim-text>CLAIMS</claim-text> <claim-text>The embodiments of the invention in which an exclusive property or privilege is claimed are defined as follows: A method (1, IA-IAE) of using a tool string (8A-8AE) and downhole device (3, 3A- 3AE) with a circumferential adaptable apparatus (2, 2A-2AE) to urge access or passage through a subterranean well bore's (10) dissimilar contiguous passageway walls (9); foirned by frictionally obstructive debris (18) within or at least a partially restricted circular or deformed circumference thereof; said method comprising the steps of: using at least one tool string comprising a deployment string (8) with lower end coiled string compatible connector (17) engaged to at least one circumferential adaptable apparatus (2) and at least one downhole device 3); depthyed in and placed or removed through a well bore's (10) upper end into or out of said well bore's (10) lower end; through intermediate dissimilar contiguous passageway walls (9) formed by first (4, 4A-4AE) and at least second (5, 5A-5AE) wall portions of substantially differing effective circumferences, debris therein, or combinations thereof; and wherein said tool string (8A-SAE) and associated deployed tools are selectively axially oriented relative to said dissimilar contiguous passageway walls (9) using said circumferential adaptable apparatus (2) comprising at least one associated axial pivotal member (7, 7A-7AE) flexibly hinged to at least one shaft segment of a plurality of movable shaft segments (6, 6A-6AE) being interoperable with said axial pivotal member (7), said downhole device (3), said tool string (8A-8AE), or combinations thereof; to engage said substantially differing effective circumferences of said dissimilar contiguous passageway walls (9) to, in use, urge access or passage by traversing a pilotable passageway between or further deforming a pilotable passageway through said frictionally obstructive debris within or at least partially restncted circular or deformed circumference of said wall portions (4, 5) forming said dissimilar contiguous passageway walls (9) of said well bore (10); to a lower end thereof
2. The method according to claim I. comprising the step of providing an actuating device comprising said string's (8) tension, said at least one actuating downhole device (3). or combinations thereof.</claim-text> <claim-text>3. The method according to claim I or claim 2, comprising the step of using said actuating at least one downhole device (3) or providing at least a second actuation downhole device (3) to operate said tool string by disposing and selectively orienting: said at least one downhole device (3); said at least one axial pivotal member (7); said at least one shaft segment; at least a second shaft segment of said plurality of movable shaft segments; said deployment string (8); or combinations thereof; wherein said tool string's interoperable tools arc sclcctivcly disposed radially, axially, or combinations thereotç to selectively orient said tool string within said dissimilar contiguous passageway walls (9) and well bore (10).</claim-text> <claim-text>4. The method according to auiy preceding claim, comprising the step of providing a circumferential adaptable apparatus (2) with a fluid passageway (24), orifice (28), valve (ii). permeable membrane (27), or combinations thereof, usable to selectively control fluid communicate within said well bore (10) and operate said tool string.</claim-text> <claim-text>5. The method according to any preceding claim, comprising the step (IA) of providing a positive fluid displacement valve (ii), momentum vibrator (12), or combinations thereof, actuating downhole device to repeatedly move and minutely reorient and operate said tool string.</claim-text> <claim-text>6. The method according to any preceding claim, comprising the step of providing a hydraulic, electric, explosive, or combination thereof, said at least one downhole device (3) or actuating downhole device.</claim-text> <claim-text>7. The method according to claim 6, comprising the step of using said at least one axial pivotal member to focus, absorb, or combinations thereof, an explosive perforating (20), explosive sculpting (19), or combination thereof, cutting downliole device forces against at least part of said dissimilar contiguous passageway walls (9).</claim-text> <claim-text>8. The method according to claim 6, comprising the step of providing an actuating downhole device (3) comprising an electric or hydraulic downhole motor (21).</claim-text> <claim-text>9. The method according to claim 5 or claim 8, comprising the step of providing a positive displacement fluid rotor and stator, fluid turbine, or combinations thereof.</claim-text> <claim-text>10. The method according to any preceding claim, comprising the step of providing an expandable, collapsible, or combinations thereof, said at least one axial pivotal member (7) usable with said actuating downhole device to control its effective diameter and operate, orient, engage or disengage said tool string to or from at least part of said dissimilar contiguous passageway walls (9).</claim-text> <claim-text>11. The method according to claim 10, comprising the step (lA) of providing said axial pivotal member (7) comprising at least one shaped or deformable: packer (34), bridge plug 35). pedal basket (22), membrane (15), mechanic arm linkage (14), wheeled mechanical linkage (26), or combination thereof.</claim-text> <claim-text>12. The method according to any preceding claim, comprising the step (IC, IE) of providing at least two shaft segments of said plurality of shaft segments with an intermediate spring like joint (23), knuckle joint (16), hinged joint (25), ball joint, or combinations thereof, usable to further operate and selectively orientate said tool string.</claim-text> <claim-text>13. The method according to any preceding claim, comprising the step of deforming said dissimilar contiguous passageway walls (9) radially outward, axially downward, or combinations thereof, to urge said access or passage.</claim-text> <claim-text>14. The method according to any preceding claim, comprising the step of operating a cutting downhole device on at least one shaft (6) of said plurality of shafts, said axial pivotal component (7), or combinations thereof, to forcibly deform at least a part of said dissimilar contiguous passageway walls (9).</claim-text> <claim-text>15. The method according to claim 14, comprising the step of further deform ing said dissimilar contiguous passageway walls (9) using a mechanical cutter (13), chemical cutter, explosive cutter, or combination thereof.</claim-text> <claim-text>16. The method according to any preceding claim, comprising the step (IA) of providing a wedging downhole device (37) on detachable shaft, a wedge formed by said axial pivotal component (7). or combinations thereof, using differential fluid pressure across said wedge to traverse said tool string, forcibly deform of at least a part of said dissimilar contiguous passageway waIls (9), or combinations thereof 17. The method according to any preceding daim, comprising the step of providing at least shaft segments further comprising at least a second shaft segment axially movable within another encompassing said shaft segment, said at least one shaft segment, or combinations thereof to further operate said tool string.18. The method according to any preceding claim, comprising the step of providing said plurality of moveable shaft segments with at least one flexible shaft, at least one rigid shaft, or combinations thereof, usable to further operate said tool string.19. The method according to any preceding claim, comprising the step of providing said plurality of moveable shaft segments with at least one rotating, at least one substantially stationary, or combination thereof, shaft segments usable to further operate said tool sUing.20. The method according to any preceding claim, compnsing the step of providing at least one dog, slip, shear pin, mandrel, or combinations thereof, holding downhole device (3) and associated receptacle to selectively engage at least two shafts of said plurality of moveable shafts.21. The method according to any preceding claim, comprising the step of traversing said dissimilar contiguous passageway waIls (9) to urge said access or passage using a hole finding orientation tool comprising an arrangement of said plurality of shafts and said at least one axial pivotal component (7) or a hole finder downhole device (3) carried by said at least one circumferential adaptable apparatus.22. The method according to any preceding daim, comprising the step of providing a plurality of pilotable passageways comprising deforming at least one smafler effective diameter pilotable passageway into a larger effective diameter pilotable passageway.23. The method according to any preceding claim, comprising the step of lining said further deformed dissimilar contiguous passageway walls (9) to form said pilotable passageway.24. The method according to any preceding claim, comprising the step of imaging said dissimilar contiguous passageway wails (9) with said at least one downhole device (3) comprising a logging tool selectively oriented by said circumferential adaptable apparatus (2) to, in use, image said dissimilar contiguous passageway walls for further selective orientation, pilotable traversing, or combinations thereof, using empirical imaging data from said logging downhole device.25. A circumferential adaptable apparatus (2, 2A-2AE) usable (1. IA-IAE) with a downhole device (3. 3A-3AE) at the lower end of a tool string (8A-8AE) to urge access or passage through a subterranean well bore's (10) dissimilar contiguous passageway walls (9); formed by frictionally obstructive debris (18) within or at least a partially restricted circular or deformed circumference thereof; said apparatus comprising: at least one associated axial pivotal member (7, 7A-7AE) flexibly hinged to at least one shaft segment of a plurality of movable shaft segments (6, 6A-6AE); usable to operate a tool string compnsing a deployment string (8) with lower end coiled string compatible connector (17) engaged to at least one circumferential adaptable apparatus (2) and at least one downhole device (3); deployed in and placed or removed through a well bore's (10) upper end into or out of said well bore's (10) lower end; through intermediate dissimilar contiguous passageway walls (9) formed by first (4, 4A-4AE) and at least a second (5. 5A-5AE) wall portions of substantially differing effective circumferences, debris therein. or combinations thereof; and wherein the interoperability of said tool string's (8) tools compriscs axially orienting shafts and members of said tools relative to said dissimilar contiguous passageway walls (9) using said circumferential adaptable apparatus's (2) engagement with said dissimilar contiguous passageway walls (9) to selectively orient said tool string (8); to traverse a pilotable passageway between or further deform said wall portions and form a pilotable passageway through said dissimilar contiguous passageway walls (9) using the interoperability between the tools deployed by said tool string (8); to, in use, urge access or passage of said tool string (8) through said frictionally obstructive debris within or at least partially restricted circular or deformed circumference of said wall portions (4. 5) forming said dissimilar contiguous passageway walls (9) of said well bore (10); to a lower end thereof.26. The apparatus according to claim 25, with said interoperability further comprising operating said tool string with a downhole actuation device comprising said string's (8) tension, said at least one downhole device (3). or combinations thereof.27. The apparatus according to claim 25 or claim 26, with said interoperability further comprising using at least a second actuation downhole device usable to operate said tool string by disposing and selectively orienting: said at least one downhole device (3); said at least one axial pivotal member (7); said at least one shaft segment; at least a second shaft segment of said plurality of movable shaft segments; said deployment string (8); or combinations thereof; wherein said tool string's interoperable tools are selectively disposed radially, axially, or combinations thereof, to selectively orient said tool siring within said dissimilar contiguous passageway walls (9) and well bore (10).28. The apparatus according to any claim 25 to 27, with said interoperability further comprising a circumferential adaptable apparatus (2) with a fluid passageway (24).orifice (28), or combinations thereof, usable to selectively control fluid communicate within said well bore (lO) and operate said tool string.29. The apparatus according to any claim 25 to 28. with said interoperability further comprising a circumferential adaptable apparatus (2) with a valve (11), permeable membrane (27), or combination thereof, usable to selectively control fluid communicate within said well bore (10) and operate said tool string.30. The apparatus according to any claim 25 to 29, with interoperability comprising an actuating downhole device with a positive fluid displacement valve (11), momentum vibrator (12), or combinations thereof (2A), usable to repeatedly move and minutely reorient and operate said tool string.31. The apparatus according to any claim 25 to 30, with said actuating downhole device (3) comprising a hydraulic, electric, explosive, or combination thereof, downhole device.32. The apparatus according to claim 31, with said explosive downhole device further comprising an explosive perforating (20), explosive sculpting (19), or combination thereof, cutting downhole device operable upon at least part of said dissimilar contiguous passageway walls (9).33. The apparatus according to claim 31, with said further interoperability comprising focusing, absorbing, or combinations thereof, said hydraulic energy, explosive energy, or combinations thereof, using said at least one axial pivotal member (7) to operate said tool string during said traversing or said further deformation of at least part of said dissimilar contiguous passageway walls (9).34. The apparatus according to claim 31, with said actuating downhole device (3) comprising an electrical or hydraulic downhole motor.35. The apparatus according to claim 30 or claim 34, with said actuating downhole device, said circumferential adaptable apparatus (2), or combinations thereof, comprising a plurality of movable shafts with: a helical nodal rotor shaft within an associated helical nodal stator housing shaft; or an inner shaft within an encompassing out housing shaft with opposing turbine blades (62) on one or more of said inner or outer encompassing shafts; wherein one shaft rotates relative to the other shaft via a differential fluid pressure applied to said helical nodes or turbine blades to communicate fluids and operate said tool string.36. The apparatus according to any claim 25 to 35, with said further interoperability further comprising selectively urging the expansion or collapse of said at least one axial pivotal member (7) using said actuating downhole device to dispose at least a second shaft segment relative to said flexibk hinge's engagement to said at least one shaft segment, wherein said expansion or collapse of said axial pivota' member (7) controls its effective diameter and operates, orients, engages or disengages said tool string to or from at least part of said dissimilar contiguous passageway walls (9).37. The apparatus according to claim 36, with said at least one axial pivotal member comprising a functionally shaped: controllably deforrnable material, substantially rigid material, or combinations thereof, usable to selectively operate said tool stung.38. The apparatus according to claim 36, with said interoperability further comprising at least one axial pivotal member comprising a packer, bridge plug, pedal basket, flexible membrane, or combination thereof.39. The apparatus according to claim 36, with said at least one axial pivotal member (7) with at least one mechanic arm linkage, at least one wheeled mechanica' linkage, or combination thereof, usable to further operate and selectivdy orientate said tool string.40. The apparatus according to any claim 25 to 39. with said tool string forcibly deforming said dissimilar contiguous passageway walls (9) radially outward, axially downward, or combinations thereof, to urge said access or passage.41. The apparatus according to any claim 25 to 40, with said interoperability further comprising operating a cutting downhole device on at least one shaft (6) of said plurality of shafts, on said at least one axial pivotal component (7), or combinations thereof, to forcibly deform at least a part of said dissimilar contiguous passageway walls (9).42. The apparatus according to claim 41, with said forcible deformation of at least a part of said dissimilar contiguous passageway walls (9) comprising the use of a mechanical cutter (1 3), chet-rilcal cutter, explosive cutter, or combination thereof, downhole device (3).43. The apparatus according to any claim 25 to 42, with said interoperability further comprising operating a wedging downhole device on detachable shaft, a wedge formed by said axial pivotal component (7), or combinations thereof, usable with differential fluid pressure across said wedge to traverse said tool string, forcibly deform of at least a part of said dissimilar contiguous passageway walls (9), or combinations thereof.43. The apparatus according to any claim 25 to 43, with said interoperability (IC, lE) further comprising at least two shaft segments of said plurahty of shaft segments with an intermediate spring like joint, knuckle joint, hinged joint, ball joint, or combinations thereof, downhole device usable to further operate and selectively orientate said tool string.45. The apparatus according to any claim 25 to 44, with said plurality of moveable shaft segments further comprising at least a second shaft segment axially movable within another encompassing said shaft segment, said at least one shaft segment, or combinations thereof to further operate said tool string.46. The apparatus according to any claim 25 to 45, with said plurality of moveable shaft segments further comprising at least substantially one flexible shaft, at east one substantially rigid shaft, or combinations thereof, usable to further operate said tool string.47. The apparatus according to ally claim 25 to 46, with said plurality of moveable shaft segments further comprising at least one substantially rotating, at least one substantially stationary. or combination thereof, shaft segments usable to further operate said tool string.48. The apparatus according to any claim 25 to 47, with said interoperability further comprising at least one dog, slip, shear pin, mandrel, or combinations thereof, holding downhole device (3) and associated receptacle to selectively engage at least two shafts of said plurality of moveable shafts.59. The apparatus according to any claim 25 to 48, with said interoperability further comprising using an arrangement of said plurality of shafts and said at least one axial pivotal component (7) to form a hole finding tool or to carry a hole finder downhole device (3), usable to locate said access or pilotable passageway and traverse through said dissimilar contiguous passageway walls (9).50. The apparatus accordhig to any claim 25 to 49. with said interoperability further comprising operating an imaging logging downhole device (3) selectively oriented by said at least one circumferential adaptable apparatus (2) to, in use, image (I AD) said dissimilar contiguous passageway walls (9) for further selective orientation, pilotable traversing, selective deformation, or combinations thereof, using empirical imaging data from said logging downhole device.51. A method of using a tool string (8) and downhole device (3) with a circumferential adaptable apparatus (2) to urge an access passageway through a subterranean well borc's (10) dissimilar contiguous passagcway walls (4, 5, 9), thc method bcing substantially as described hereinabove with reference to Figures 2 to 3, Figures 6 to 7, Figures II to 20, Figures 23, Figure 25, Figures 27 to 48, Figure 27A. Figure 37A and Figures 51 to 64 of the accompanying drawings Figures.52. An apparatus comprising a circumferential adaptable apparatus (2, 2A-2Z) usable (I, 1A-1Z) with a downhole device (3. 3A-3Z) at the lower end of a tool string (8) to urge access or passage through a subterranean well bore's (10) dissimilar contiguous passageway walls (9), said apparatus being substantially as described hereinabove with reference to Figures 2 to 3, Figures 6 to 7, Figures II to 20. Figures 23, Figure 25, Figures 27 to 48, Figure 27A, Figure 37A and Figures 51 to 64 of the accompanying drawings Figures.</claim-text>