Office Action 1: Non-Final Rejection (2024-07-30)
Rejection types: 103 - Obviousness, 112 - Written Description/Enablement

CLAIMS:
CLAIMS

WHAT IS CLAIMED IS:

1\. An insertion tool assembly for disposing a back-pressure valve (BPV) in a tubing hanger installed in a wellhead of a well, the insertion assembly configured to isolate pressure from the well when attached to a top-most crown of the wellhead and the BPV configured to, when disposed in the tubing hanger, prevent fluid flow from the well through the wellhead while permitting fluid to be pumped into the well, the insertion tool assembly comprising:a lubricator comprising a rod slidably disposed therein, the rod configured such that the BPV can be releasably attached to a distal end of the rod;
a tubular adapter comprising:
a main body with a top end and a bottom end and a central bore therethrough, the top end detachably attached to the lubricator and the bottom end configured to be detachably attached to the crown top of the wellhead, wherein an internal diameter of the central bore is greater than an external diameter of the BPV; and
a kill fluid port disposed through a side-wall of the main body, wherein the insertion tool assembly is configured such that, when the BPV is attached to the distal end of the rod and the bottom end of the tubular adapter is attached to the crown top:
the BPV can pass through the tubular adapter and into the wellhead through the crown top as the rod is extended from the lubricator; and a kill fluid injected into the kill fluid port can flow through the crown top into the well.

2\. The insertion tool assembly of claim 1, wherein the insertion tool assembly is configured such that, when a crown valve of the wellhead is open, the kill fluid flowing into the tubular adapter flows vertically through the crown top into the well through the crown valve.

3\. The insertion tool assembly of claim 1, wherein the insertion tool assembly is configured such that, when kill fluid flows through the crown top into the well, all wellhead valves through which the rod can pass when extended are open.
4\. The insertion tool assembly of claim 1, wherein the kill fluid flowing through the crown top into the well flows through the BPV.
5\. The insertion tool assembly of claim 1, wherein the BPV, when attached to the distal end and the rod fully retracted, does not extend past the bottom end.
6\. The insertion tool assembly of claim 1, wherein the insertion tool assembly is configured such that injection of a fluid into the kill fluid line port from the fluid line dislodges debris within the central bore.
7\. The insertion tool assembly of claim 1, wherein the assembly is configured such that the crown top of the wellhead can remain closed as the bottom end is attached to the bottom end and can be opened after attaching the bottom end to the crown top.
8\. A method comprising:
attaching, to a crown top of a wellhead of a well, an insertion tool assembly for disposing a back-pressure valve (BPV) in a tubing hanger installed in a wellhead, the insertion tool assembly comprising:
a lubricator comprising a rod slidably disposed therein, the rod configured such that the BPV can be releasably attached to a distal end of the rod; and
a tubular adapter comprising:
a main body with a top end and a bottom end and a central bore therethrough, the top end detachably attached to the lubricator and the bottom end configured to be detachably attached to the crown of the wellhead, wherein an internal diameter of the central bore is greater than an external diameter of the BPV; and a kill fluid port disposed through a side-wall of the main body;

extending the rod and thereby passing the BPV through the tubular adapter and into the wellhead through the crown top; and
in response to a well control event indication, injecting a kill fluid into the kill fluid port, thereby flowing kill fluid through the crown top into the well.
9\. The method of claim 8, wherein the kill fluid flowing through the crown top into the well flows into the well through an open, top-most valve of the wellhead below the crown top.

10\. The method of claim 8, wherein, when the kill fluid flows through the crown top into the well, all wellhead valves through which the rod is configured to pass when the rod is extended are open.

11\. The method of claim 8, wherein the kill fluid flowing through the crown top into the well does not flow through the BPV to the crown top when the rod is in a retracted position.

12\. The method of claim 8, wherein the kill fluid flowing through the crown top into the well flows through the BPV.

13\. The method of claim 8, wherein the insertion assembly is configured such that, when the BPV is attached to the distal end and the rod fully retracted, the BPV does not extend past the bottom end.

14\. The method of claim 8, wherein the insertion tool assembly is configured such that injection of a fluid into the kill fluid line port from the fluid line dislodges debris within the central bore.

15\. The method of claim 14, wherein the insertion tool assembly is configured such that the injection of the fluid occurs uphole of the BPV while the BPV is fully retracted into the tubular adapter.

16\. A method comprising:

attaching a top end of a tubular adapter to a lubricator, the lubricator comprising a rod slidably disposed therein, the rod configured such that a BPV can be releasably attached to a distal end of the rod, the tubular adapter comprising:a main body with a top end and a bottom end and with a central bore therethrough; and
a kill fluid port disposed through a side-wall of the main body;
while maintaining a crown top valve of a crown top of a wellhead of a well closed and the rod fully retracted such that the BPV attached to its distal end is within the central bore and above the bottom end, attaching the bottom end of the tubular adapter to the crown top;
after attaching the bottom end to the crown top, opening the crown top valve;
after opening the crown top valve, extending the rod and thereby passing the BPV out the bottom end of the tubular adapter and into the wellhead through the crown top; and
after the extending, retracting the BPV from the wellhead with the rod and into the central bore of the tubular adapter above the bottom end and thereafter closing the crown top valve while the bottom end remains attached to the crown top.

17\. The method of claim 16, further comprising, in response to a well control event indication while the bottom end of the tubular adapter is attached to the crown top and the crown valve is open, injecting a kill fluid into the kill fluid port, thereby flowing kill fluid through the crown top into the well.

18\. The method of claim 16, further comprising injecting a fluid comprising a surfactant into the kill fluid port in response to an indication of debris on or proximate the BPV.

19\. The method of claim 18, wherein the insertion tool assembly is configured such that the injection of the fluid occurs uphole of the BPV while the BPV is fully retracted into the tubular adapter.

20\. The method of claim 16, wherein the insertion assembly is configured such that, when the BPV is attached to the distal end and the rod fully retracted, the BPV does not extend past the bottom end.

OFFICE ACTION:
DETAILED ACTION
Notice of Pre-AIA  or AIA  Status
The present application, filed on or after March 16, 2013, is being examined under the first inventor to file provisions of the AIA . The claims of 8 Sep 2023 have been entered.
Drawings
The drawings are objected to as failing to comply with 37 CFR 1.84(p)(5) because they include the following reference character(s) not mentioned in the description:
Fig 2B #200 is undefined.
Corrected drawing sheets in compliance with 37 CFR 1.121(d), or amendment to the specification to add the reference character(s) in the description in compliance with 37 CFR 1.121(b) are required in reply to the Office action to avoid abandonment of the application. Any amended replacement drawing sheet should include all of the figures appearing on the immediate prior version of the sheet, even if only one figure is being amended. Each drawing sheet submitted after the filing date of an application must be labeled in the top margin as either “Replacement Sheet” or “New Sheet” pursuant to 37 CFR 1.121(d). If the changes are not accepted by the examiner, the applicant will be notified and informed of any required corrective action in the next Office action. The objection to the drawings will not be held in abeyance.
Claim Rejections - 35 USC § 112
The following is a quotation of 35 U.S.C. 112(b):
(b)  CONCLUSION.—The specification shall conclude with one or more claims particularly pointing out and distinctly claiming the subject matter which the inventor or a joint inventor regards as the invention.
The following is a quotation of 35 U.S.C. 112 (pre-AIA ), second paragraph:
The specification shall conclude with one or more claims particularly pointing out and distinctly claiming the subject matter which the applicant regards as his invention.
Claim(s) 8-20 are rejected under 35 U.S.C. 112(b) or 35 U.S.C. 112 (pre-AIA ), second paragraph, as being indefinite for failing to particularly point out and distinctly claim the subject matter which the inventor or a joint inventor (or for applications subject to pre-AIA  35 U.S.C. 112, the applicant), regards as the invention.
Claim 8 is unclear if the back pressure valve (BPV) is attached to the distal end of the rod, only reciting configured, interpreted as capable to be attached. It is suggested to positively recite wherein the BPV IS releasably ATTACHED. Claim(s) 9-15 are dependent from claim 8 and are therefore also rejected under indefiniteness.
Claim 16 recites “BPV” on line 3, without first defining the abbreviation. This would be required on all independent claims upon its first introduction. Claim(s) 17-20 are dependent from claim 16 and are therefore also rejected under indefiniteness.
Claim(s) 19 and 20 recite “the insertion tool assembly” and “the insertion assembly”, respectively on line 1. There is insufficient antecedent basis for this limitation in the claim.
Claim Rejections - 35 USC § 103
The following is a quotation of 35 U.S.C. 103 which forms the basis for all obviousness rejections set forth in this Office action:
A patent for a claimed invention may not be obtained, notwithstanding that the claimed invention is not identically disclosed as set forth in section 102, if the differences between the claimed invention and the prior art are such that the claimed invention as a whole would have been obvious before the effective filing date of the claimed invention to a person having ordinary skill in the art to which the claimed invention pertains. Patentability shall not be negated by the manner in which the invention was made.
Claim(s) 1-8 and 12-14 are rejected under 35 U.S.C. 103 as being unpatentable over Ronne (WO 2019027448) in view of Jaffrey (US 20170167220) and Lantier, Sr et al. (USP 5,320,181) and Bowen, Jr et al. (US 20180003002).
Regarding claim(s) 1 and 4, Ronne discloses an insertion tool assembly (#300) for disposing a tubular obturator (‘Fig 4d #472 – ‘crown plug’) in a tubing hanger (Fig 4 #352) installed Fig 4F) in a wellhead of a well,
the insertion assembly [#300] configured to isolate pressure (#350 and/or #307 explained ¶0053) from the well when attached (Fig 4C-4E) to a top-most crown of the wellhead and
the obturator [#472] configured to, when disposed (Fig 4D or 4E) in the tubing hanger [#352], the insertion tool assembly comprising:
a lubricator (#302) comprising a rod (#309 – piston stem) slidably disposed therein, the rod configured (Fig 4b-4e) such that the obturator [#472] can be releasably attached to a distal end of the rod;
a tubular adapter (Fig 1 #113 – ‘spool assembly’ with #104 similar in Fig 4a-e) comprising:
a main body (#113/104) with a top end (‘bonnet connection) and a bottom end (#178) and a central bore (Fig 1 #114) therethrough, the top end detachably attached (Fig 1 explained ¶0033 – “the open water lubricator #102 may include an upper assembly #107 coupled to a spool assembly #113”) to the lubricator [#102] and
the bottom end configured to be detachably attached to the crown top (interpreted as top surface) of the wellhead (Fig 4B #352), wherein an internal diameter of the central bore is greater (seen in Fig #4D) than an external diameter of the BPV [#450]; and
the obturator [#472] can pass through the tubular adapter [#113 and 104] and into the wellhead [#352] through the crown top as the rod [#309] is extended from the lubricator; and
Ronne does not explicitly disclose:
a kill fluid port disposed through a side-wall of the main body, wherein the insertion tool assembly is configured such that, when the BPV is attached to the distal end of the rod and the bottom end of the tubular adapter is attached to the crown top:
a kill fluid injected into the kill fluid port can flow through the crown top into the well.
a valve configured to prevent fluid flow from the well through the wellhead while permitting fluid to be pumped into the well.
Jaffrey teaches in ¶0024 – “Each BOP typically comprises one or more choke or kill fluid ports located below the closing elements [e.g., rams] of the BOP. The choke or kill ports provide a conduit for pumping fluid into or out of the wellbore while the associated closing elements are closed in the event of a well kick”.
It would have been obvious to one of ordinary skill in the art before the effective filing date of the claimed to include injecting a kill fluid via the one or more kill fluid port(s) as taught by Jaffrey in the system of Ronne, with a reasonable expectation of success, since the claimed invention is merely a combination of old elements, and in the combination each element merely would have performed the same function as it did separately, and one of ordinary skill in the art would have recognized that the combination would result in the predictable result of preventing a well kick by the injection of the kill fluid within the well.
Lantier teaches a combination two-way check valve and back pressure valve (title) for use in a workover well operation. Further teaching (Col 2 line 21 – “Operating piston means, disposed within the bore of the pressure piston means, are provided for blocking the flow in; and (Col 3 line 1 – “If the formation begins to build-up pressure subsequent to pressure testing the blow out preventers, pressure to the top of the valve is increased until the predetermined amount of force is reached so that the selective dis-attachment means is actuated. Then fluid is pumped through the combination valve and down the tubing string. Continued pumping will equalize the hydrostatic pressure within the tubing string, i.e., killing the pressure from the formation.” Lantier teaches the advantage of using a check valve is that once in place, the blow-out preventer stack can be pressure tested for any leaks in the stack, manifold, etc. (Col 1 line 32) and a traditional back pressure valve can be used to equalize the hydrostatic pressure when the formation pressure backs up, fluid can be pumped through the back pressure valve and down the tubing string thereby creating a balanced hydrostatic head (Col 1 line 43).
It would have been obvious to one of ordinary skill in the art before the effective filing date of the claimed to substitute the Lantier #2 combination valve for the Ronne #472 (‘crown plug’), with a reasonable expectation of success, since the claimed invention is merely a combination of old elements, and in the combination each element merely would have performed the same function as it did separately, and one of ordinary skill in the art would have recognized that the combination would result in the predictable result of being able to pressure test for any leaks in the BOP stack, manifold, etc. and avoiding the required step of rig down the BOP, reinstall the Christmas tree, remove the two-way check valve, located in its place the traditional back pressure valve and pump fluid down the tubing string (Col 1 line 49).
Bowen teaches “a pressure control valve located in an improved tubing hanger of an oil or gas wellhead. … The pressure actuates the in-line wellhead control valve in a safer, more efficient, and less expensive manner that current industry practices and provides a barrier to pressurized hydrocarbons, both liquid and gas, produced by the well” – abstract. “The present invention will accomplish in minutes using basic hand tools, what can typically take hours using expensive and dangerous equipment. With the present invention, a single person using a hydraulic hand pump and wrench can gain well control in five to fifteen minutes without the need for a crane or a crew” - ¶0018. ¶0023 describes how the sealing valve is opened only after pressure above the valve is equalized to force the valve to open.
It would have been obvious to one having ordinary skill in the art, given the teaching of Bowen, to substitute the “large crown plug” #356 of Ronne with the “test-port activated tubing hanger control valve” Fig 1 of Bowen for the purpose of increasing safety of personnel while minimizing costs and time associated with the equipment required to place Ronne’s valve. It is noted that the increased pressure of the kill fluid would open Bowen’s valve and allow fluid to enter into the wellbore.
Additionally, regarding claim 8, Jaffrey of the combination teaches (¶0024 – “Such a blowout might occur, for example, when the well intersects a pocket of fluid under high pressure, which then blows up through the wellbore. A BOP can also be used to seal off the well against the fluid pressure from below. … The choke or kill ports provide a conduit for pumping fluid into or out of the wellbore while the associated closing elements are closed in the event of a well kick”.
It would have been obvious to one having ordinary skill in the art before the effective filing date of the claimed invention to prevent the uncontrolled expansion of high-pressure fluids from exiting the wellbore by the use of the BOP and kill fluid disposed in the wellbore in response to a well control event, as well-known in the art. It is noted that the increased pressure of the kill fluid would open Bowen’s valve and allow fluid to enter into the wellbore.
Regarding claim 2, Ronne of the combination discloses wherein the insertion tool assembly [#300] is configured (interpreted as capable) such that, when a crown valve (“test-port activated tubing hanger control valve” of Bowen) of the wellhead [#352] is open, the kill fluid flowing (from ports located below the BOP, as taught by Jaffrey) into the tubular adapter [#113/104] flows vertically through the crown top [‘top surface’] into the well through the crown valve (interpreted as the plug seat without plug).
Regarding claim(s) 3 and 10, combination discloses a contained volume between the lower valve of Bowen to the lubricator piston assembly therefore all wellhead valves are capable to be open when fluid flows through the crown top into the well.
Regarding claim(s) 5 and 13, the combination discloses wherein the BPV [“test-port activated tubing hanger control valve” of Bowen], when attached to the distal end and the rod fully retracted (Ronne - Fig 4c), does not extend past (Ronne Fig 4c) the bottom end.  It is noted, that the examiner is taking the understanding that “the insertion assembly” is referring to the “insertion tool assembly” of claim 8. Clarification or correction is requested.
Regarding claim(s) 6 and 14, Jaffrey of the combination discloses wherein the insertion tool assembly [#300] is configured (interpreted as capable) such that injection of a fluid into the kill fluid line port from the fluid line dislodges debris within the central bore.
It would have been obvious to one having ordinary skill in the art before the effective filing date of the claimed invention to realize that a high-pressure injection of fluid would at least be capable to dislodge loose particles within the central bore.
Regarding claim 7, Ronne discloses the insertion tool assembly of claim 1, wherein the assembly [interpreted as the insertion tool assembly] is configured (interpreted as capable) such that the crown top [top surface] of the wellhead can remain closed (“test-port activated tubing hanger control valve” of Bowen) as the bottom end [#178] is attached to the bottom end and can be opened after attaching the bottom end to the crown top.
It would have been obvious to one having ordinary skill in the art before the effective filing date of the claimed invention to realize that the lower crown plug might be safely removed AFTER the connection of the BOP to the upper portion of the wellbore, given the fluid blocking properties of the BOP.
Regarding claim 11, the combination discloses claim 8, and it would be obvious to realize that if the BPV is attached to the distal end of the rod and the rod is retracted position, then any fluid flowing down the wellbore would not flow through the BPV, as the BPV would be located uphole from the fluid port.
Regarding claim(s) 9 and 12, the combination discloses claim 8 and further discloses wherein the fluid flowing through the crown top into the well flows into the well through an open, top-most valve (Bowen’s valve due to pressure differential) of the wellhead below the crown top.
Claim(s) 16 and 20 are rejected under 35 U.S.C. 103 as being unpatentable over El Sayed (US 20220290524) maybe in view of Villa (US 20120024521).
Regarding claim 16, El-Sayed discloses attaching (¶0052) a top end of a tubular adapter (BOP Stack #80) to a lubricator (#10),
the lubricator comprising a rod (#12) slidably disposed (¶0054 – polished rod #12 that can be moved up and down”) therein, the rod configured (¶0054 – “polished rod #12 of the lubricator #10 comprises at the lower end thereof a first high torque connection #14 that is compatible a dry rod #30 for a connection with back pressure valves [BPV]”) such that a BPV (interpreting as  Valve - El-Sayer #120) can be releasably attached (¶0054 – “connection #14 will be high torque connection … to tight or release the tubing hanger plugs”) to a distal end of the rod, the tubular adapter comprising:
a main body [BOP stack #80] with a top end (Fig 1 top) and a bottom end (Fig 1 bottom) and with a central bore (¶0055 – “riser #20 is capable of running through the BOP stack #80”) therethrough; and
a kill fluid port (Fig 1 #82) disposed through a side-wall of the main body [BOP Stack];
El-Sayed further discloses “the through BOP lubrication system #1 is a complete system of high pressure rated equipment assembled together to provide full pressure control system during installing and retrieving the Back Pressure Valve (#120) or any other plugging device in the tubing hanger profile that well act as secondary well barrier” - ¶0052; however, does not explicitly disclose the following steps:
while maintaining a crown top valve of a crown top of a wellhead of a well closed and the rod fully retracted such that the BPV attached to its distal end is within the central bore and above the bottom end, attaching the bottom end of the tubular adapter [BOP stack] to the crown top [wellhead];
after attaching the bottom end to the crown top, opening the crown top valve;
after opening the crown top valve, extending the rod and thereby passing the BPV out the bottom end of the tubular adapter and into the wellhead through the crown top; and
after the extending, retracting the BPV from the wellhead with the rod and into the central bore of the tubular adapter above the bottom end and thereafter closing the crown top valve while the bottom end remains attached to the crown top.
Villa teaches (¶0030 – “the lubricator, with a back pressure valve attached, is mounted on the top of the Christmas tree” … ¶0031 – “the polished tool rod is extended down through the tree by regulated hydraulic force, allowing the threaded BPV to be screwed into the threaded top of the well’s tubing hanger. The rod is then retrieved under the controlled hydraulic power. The lubricator may then be removed from the tree”).
It would have been obvious to one having ordinary skill in the art, given the teaching of Villa as applied to operation of El-Sayed to realize wellhole pressure control would require the top valve to be closed prior to the attachment to provide wellbore containment and the opened to allow the insertion of the BPV into the well, pass the valve.
after the extending, retracting the BPV (¶0031 - “After maintenance or repair has been completed, or the down-hole tool placed, the BPV must be retrieved to resume productive operation of the well. The lubricator is again connected to the tree cap, and the tool rod again hydraulically inserted down into the tree. Pressure in the tree can then again be equalized, and the BPV engaged and removed using the lubricator”) from the wellhead with the rod and into the central bore of the tubular adapter above the bottom end and thereafter closing the crown top valve while the bottom end remains attached to the crown top.
It would have been obvious to one of ordinary skill in the art before the effective filing date of the claimed to include the process of removing the BPV as taught by Villa in the system of El-Sayed, with a reasonable expectation of success, since the claimed invention is merely a combination of old elements, and in the combination each element merely would have performed the same function as it did separately, and one of ordinary skill in the art would have recognized that the combination would result in the predictable result of maintaining well pressure control during the installing and removal of wellbore plug.
Regarding claim 20, the combination discloses wherein the insertion assembly (Fig 10) is configured such that, when the BPV [Fig 10 #120] is attached to the distal end and the rod fully retracted (Fig 10), the BPV does not extend past the bottom end [base of BOP stack].
Claim(s) 17 is rejected under 35 U.S.C. 103 as being unpatentable over El Sayed and Villa as applied to claim 16 above, and further in view of Santos (US 20110214882).
Regarding claim 17, the combination of El Sayed and Villa discloses the method of claim 16; however, does not explicitly further comprising, in response to a well control event indication while the bottom end of the tubular adapter is attached to the crown top and the crown valve is open, injecting a kill fluid into the kill fluid port, thereby flowing kill fluid through the crown top into the well.
Santos teaches ‘System and Method for Safe Well Control Operations’ – title and further teaches ¶0006 – “a primary function of the fluid is to maintain a primary barrier inside the well bore to prevent formation fluids from entering the wellbore and flowing to the surface.” And ¶0007 – “when a kick is taken, the invading formation liquid and/or gas may ‘cut’ or decrease, the density of the fluid in the wellbore annulus, such that an increasing amount of formation fluid enters the well bore. Such an occurrence may be noted at the drilling rig in the form of 1) a change in pressure in the well bore annulus, 2) a change in fluid density, and/or 3) again in fluid volume in the fluid system tanks. … Before resuming operations, a known well-killing procedure may be followed to circulate the kick out of the wellbore, circulate an appropriate weighted fluid (‘kill fluid’) into the wellbore [via #34 kill line] and ensure that well control has been safely regained.”
It would have been obvious to one having ordinary skill in the art before the effective filing date of the claimed invention, given the teaching of Santos, with reasonable expectation of success to inject a kill fluid into the wellbore via the kill fluid port for the purpose of regaining well control after a well control event indication.
Claim(s) 18 is rejected under 35 U.S.C. 103 as being unpatentable over El Sayed and Villa as applied to claim 16 above, and further in view of Mason et al. (US 20120220501).
Regarding claim 18, the combination discloses the method of claim 16; however, does not explicitly disclose further comprising injecting a fluid comprising a surfactant into the kill fluid port in response to an indication of debris on or proximate the BPV.
Mason teaches ‘Non-Aqueous, Acid Soluble, High-Density Completion Fluids and Process’ further teaching “the anionic sulfonate surfactants function well in preventing the formation of aqueous acid-crude oil emulsions and prevent oil sludging from taking place” - ¶0005.
It would have been obvious to one having ordinary skill in the art before the effective filing date of the claimed invention, given the teaching of Mason, to inject a fluid containing a surfactant, with a reasonable expectation of success, into the wellbore for the purpose to prevent emulsions and sludging buildups from within the wellbore.
Allowable Subject Matter
Claim(s) 15 and 19 would be allowable if rewritten to overcome the rejection(s) under 35 U.S.C. 112(b) or 35 U.S.C. 112 (pre-AIA ), 2nd paragraph, set forth in this Office action and to include all of the limitations of the base claim and any intervening claims.
The following is a statement of reasons for the indication of allowable subject matter:
Regarding claim(s) 15 and 19, the combination discloses wherein the fluid would be injected below the BOP, not above the BPV while fully retracted into the tubular adapter.
Conclusion


NEXT OFFICE ACTION: DETAILED ACTION
Notice of Pre-AIA  or AIA  Status
The present application, filed on or after March 16, 2013, is being examined under the first inventor to file provisions of the AIA . The amendments of 22 Oct 2024 have been entered.
Response to Arguments
Applicant’s arguments, see Remarks page 8 line 9, filed 22 Oct 2024, with respect to the drawings have been fully considered and are persuasive.  The objection of 30 Jul 2024 has been withdrawn.
Applicant’s arguments, see Remarks page 8 line 15, filed 22 Oct 2024, with respect to claim(s) 8-20 have been fully considered and are persuasive.  The rejection of 30 Jul 2024 has been withdrawn.
Applicant’s arguments, see Remarks page 8 line 18, filed 22 Oct 2024, with respect to claim(s) 1, 8 and 16 have been fully considered and are persuasive.  The rejections of 30 Jul 2024 have been withdrawn.
EXAMINER’S AMENDMENT
An examiner’s amendment to the record appears below. Should the changes and/or additions be unacceptable to applicant, an amendment may be filed as provided by 37 CFR 1.312. To ensure consideration of such an amendment, it MUST be submitted no later than the payment of the issue fee.
The application has been amended as follows:
In the claim:
Claim 13 line 1 “wherein the insertion assembly” has been changed –wherein the insertion tool assembly--.
Allowable Subject Matter
Claim(s) 1-13, 16, 17 and 20 are allowed.
The following is an examiner’s statement of reasons for allowance:
The prior art Ronne (WO 2019027448), Jaffrey (US 20170167220), Lantier Sr. (USP 5,320,181), Bowen Jr et al (US 20180003002), El Sayed (US 20220290524), Villa (US 20120024521), Santos (US 20110214882) and Mason et al. (US 20120220501). The prior art discloses wherein the fluid is injected below the BPV, not above the BPV while fully retracted into the tubular adapter.
Any comments considered necessary by applicant must be submitted no later than the payment of the issue fee and, to avoid processing delays, should preferably accompany the issue fee.  Such submissions should be clearly labeled “Comments on Statement of Reasons for Allowance.”
Conclusion

CITED REFERENCE SUMMARIES: Ref US20170167220A1: Claims:
A rain blowout preventer (âBOPâ) assembly, comprising: a body comprising a vertical bore extending through the body, a rain cavity intersecting the bore, and a port located below the rain cavity; a pair of opposing rams movable laterally into and out of the BOP vertical bore; and a sensor assembly located in the port and configured to monitor the position of at least one opposing rain.
a body comprising a vertical bore extending through the body, a rain cavity intersecting the bore, and a port located below the rain cavity;
a pair of opposing rams movable laterally into and out of the BOP vertical bore; and
a sensor assembly located in the port and configured to monitor the position of at least one opposing rain.
The assembly of claim 1 , wherein each opposing rain comprises a detection feature located on a lower surface of the rain and configured to be detected by the sensor assembly.
The assembly of claim 2 , wherein the detection feature comprises a visual indicator.
The assembly of claim 2 , wherein the detection feature comprises a radio frequency identification (âRFIDâ) tag.
The assembly of claim 1 , wherein the sensor assembly is configured to be calibrated depending on a velocity of sound of a fluid in the vertical bore.
The assembly of claim 1 , wherein the sensor assembly is configured to monitor the position of each opposing rain during movement of each rain.
The assembly of claim 1 , further comprising another port configured to provide for fluid communication with the vertical bore.
The assembly of claim 7 , wherein the another port is a choke or kill port.
The assembly of claim 1 , comprising multiple sensors located in the port configured to monitor the position of each opposing rain.
The assembly of claim 1 , where the sensor assembly is powered by a power source local to the blowout preventer assembly.
The assembly of claim 1 , wherein the opposing rams are each one of a shear rain, a pipe rain, variable-bore rain, blind shear rain, or a blind rain.
The assembly of claim 1 , wherein the sensor is configured to be retrofitted to the port.
A blowout preventer (âBOPâ) rain detection assembly for detecting the position of a rain in a BOP assembly, the detection assembly comprising: a rain moveable within the BOP assembly and comprising a detection feature located on a lower surface of the rain; a sensor assembly locatable in the BOP assembly and configured to detect the position of the rain by detecting the detection feature.
a rain moveable within the BOP assembly and comprising a detection feature located on a lower surface of the rain;
a sensor assembly locatable in the BOP assembly and configured to detect the position of the rain by detecting the detection feature.
The assembly of claim 13 , wherein the detection feature comprises a visual indicator.
The assembly of claim 13 , wherein the detection feature comprises a radio frequency identification (âRFIDâ) tag.
The assembly of claim 13 , wherein the sensor is configured to be calibrated depending on a velocity of sound of a fluid in the vertical bore.
The assembly of claim 13 , wherein the sensor assembly is configured to monitor the position of the rain during movement of the rain.
The assembly of claim 13 , wherein the detection feature is retrofittable to the rain.
The assembly of claim 13 , further comprising a plurality of detection features.
A method for monitoring the position of a rams within a blowout preventer (âBOPâ), comprising: providing a detection feature on a lower surface of the rain; providing a sensor assembly in a port located in the BOP below the rain; moving the rain within the BOP; and monitoring the position of the rain by detecting the detection feature with the sensor assembly.
providing a detection feature on a lower surface of the rain;
providing a sensor assembly in a port located in the BOP below the rain;
moving the rain within the BOP; and
monitoring the position of the rain by detecting the detection feature with the sensor assembly.
Ref US5320181A: Claims:
A valve, comprising: a cylindrical body with a bore therethrough, said body containing a sealing shoulder, and a portion defining a first and second port; a pressure piston, disposed within said bore of said cylindrical body, said pressure piston containing a central passageway therethrough and a sealing surface; first holding means for holding said pressure piston in a first position relative to said cylindrical body; operating stem means, disposed within said bore of said pressure piston, for blocking flow in either axial direction, said operating piston means having a sealing surface which cooperates with the sealing surface of said pressure piston.
a cylindrical body with a bore therethrough, said body containing a sealing shoulder, and a portion defining a first and second port;
a pressure piston, disposed within said bore of said cylindrical body, said pressure piston containing a central passageway therethrough and a sealing surface;
first holding means for holding said pressure piston in a first position relative to said cylindrical body;
operating stem means, disposed within said bore of said pressure piston, for blocking flow in either axial direction, said operating piston means having a sealing surface which cooperates with the sealing surface of said pressure piston.
The valve of claim 1, further comprising: biasing means, disposed about said operating piston means, for biasing said operating piston means against the sealing shoulder of said cylindrical body; compression means, disposed about said operating piston means and abutting said biasing means, for holding said biasing means in compression; and wherein said pressure piston contains a second sealing surface, and wherein said operating piston contains a second sealing surface so that the second sealing surface of said pressure piston cooperates with the second sealing surface of said operating piston.
biasing means, disposed about said operating piston means, for biasing said operating piston means against the sealing shoulder of said cylindrical body;
compression means, disposed about said operating piston means and abutting said biasing means, for holding said biasing means in compression;
and wherein said pressure piston contains a second sealing surface, and wherein said operating piston contains a second sealing surface so that the second sealing surface of said pressure piston cooperates with the second sealing surface of said operating piston.
The valve of claim 2, wherein said cylindrical body has contained thereon an aperture, said pressure piston has contained thereon a groove, and wherein said first holding means comprises a shear pin fitter within said apertures.
The valve of claim 3, wherein said cylindrical body further contains a second aperture and wherein said compression means includes: a shear piston, disposed about said operating piston, containing a groove thereon; a shear pin fitter through the second of said cylindrical body and shear piston, and wherein said biasing means includes a spring disposed about said operating piston, and urging said shear piston axially upward; and wherein said shear pins are preselected to shear after a predetermined amount of force has been applied.
a shear piston, disposed about said operating piston, containing a groove thereon;
a shear pin fitter through the second of said cylindrical body and shear piston, and wherein said biasing means includes a spring disposed about said operating piston, and urging said shear piston axially upward; and wherein said shear pins are preselected to shear after a predetermined amount of force has been applied.
The valve of claim 4, wherein said shear pins are preselected to shear at a pressure of 3500 psi.
The valve of claim 4, further comprising: lock means, disposed within said bore of said cylindrical body, for locking said pressure piston in a down position after the predetermined amount of force has been applied to shear said pins.
lock means, disposed within said bore of said cylindrical body, for locking said pressure piston in a down position after the predetermined amount of force has been applied to shear said pins.
An apparatus to control the flow in a well bore comprising: a cylindrical member having an inlet port and an outlet port, said cylindrical member having an axial bore therethrough with a sealing bore thereon; a valve sleeve, slidably disposed within said axial bore of said cylindrical member and attached thereto, said valve sleeve having an inner diameter therethrough, and a sealing shoulder thereon; selective dis-attachment means for attaching said cylindrical member to said valve sleeve; a valve stem, slidably disposed within said axial bore of said valve sleeve, said valve stem containing a first and second shoulder, with the first shoulder cooperating with the sealing bore of said cylindrical member, and the second shoulder cooperating with the sealing bore of said valve sleeve.
a cylindrical member having an inlet port and an outlet port, said cylindrical member having an axial bore therethrough with a sealing bore thereon;
a valve sleeve, slidably disposed within said axial bore of said cylindrical member and attached thereto, said valve sleeve having an inner diameter therethrough, and a sealing shoulder thereon;
selective dis-attachment means for attaching said cylindrical member to said valve sleeve;
a valve stem, slidably disposed within said axial bore of said valve sleeve, said valve stem containing a first and second shoulder, with the first shoulder cooperating with the sealing bore of said cylindrical member, and the second shoulder cooperating with the sealing bore of said valve sleeve.
The apparatus of claim 7, further comprising: biasing means, disposed about said valve stem, for biasing said valve stem in a closed position; holding means, operably connected to said cylindrical member and said valve stem, for holding the biasing means in compression.
biasing means, disposed about said valve stem, for biasing said valve stem in a closed position;
holding means, operably connected to said cylindrical member and said valve stem, for holding the biasing means in compression.
The apparatus of claim 8, wherein said cylindrical member contains an aperture therein, and said valve sleeve also contains an aperture; and, wherein said selective dis-attachment means comprises a shear pin positioned within said apertures of said cylindrical member and valve sleeve.
wherein said selective dis-attachment means comprises a shear pin positioned within said apertures of said cylindrical member and valve sleeve.
The apparatus of claim 9, wherein said biasing means includes a spring disposed about said valve stem, and tending to bias said valve stem in an axial upward direction.
The apparatus of claim 10, wherein said cylindrical member contains a second aperture, and wherein said holding means includes a shear piston having a circumferential groove, and a shear pin placed within said second aperture of said cylindrical member and said groove of said shear piston so that said shear piston holds said spring in compression; said shear pins being selected to shear at a predetermined amount of pressure applied to the apparatus.
The apparatus of claim 11, further comprising reinforcement means, located about the periphery of the valve, for adding reinforcement structure to the valve during installation and removal operations.
The apparatus of claim 11, further comprising: lock means, disposed within said axial bore of said cylindrical member, for said valve sleeve in a down position after the predetermined amount of force has been applied to the apparatus to shear said pins.
lock means, disposed within said axial bore of said cylindrical member, for said valve sleeve in a down position after the predetermined amount of force has been applied to the apparatus to shear said pins.
A method of installing a combination two-way check valve and back pressure valve in a receptacle located in a tubing string penetrating an underground formation during remedial workover operations, the tubing string having attached thereto a surface control valve, the method comprising the steps of: a. placing in the landing receptacle the combination valve utilizing a lubricator connected to the surface control valve, said combination valve comprising: a cylindrical body; a pressure piston; first and second selective dis-attachment means responsive to a pressure force; operating piston means; biasing means for biasing said operating piston in a closed position; b. removing the surface control valve; c. installing a stack of blow-out preventers, the blow-out preventers being connected to the tubing string; d. pressure testing the blow-out preventers for proper installation by applying pressure to the top of said combination valve.
a. placing in the landing receptacle the combination valve utilizing a lubricator connected to the surface control valve, said combination valve comprising: a cylindrical body; a pressure piston; first and second selective dis-attachment means responsive to a pressure force; operating piston means; biasing means for biasing said operating piston in a closed position;
b. removing the surface control valve;
c. installing a stack of blow-out preventers, the blow-out preventers being connected to the tubing string;
d. pressure testing the blow-out preventers for proper installation by applying pressure to the top of said combination valve.
The method of claim 11, wherein pressure from the formation builds in the tubing string, and further comprising the steps of: e. creating a pressure to the top of the combination valve until a predetermined amount of pressure has been reached so that the selective dis-attachment means is actuated; f. pumping a fluid through the combination valve and down the tubing string to create a hydrostatic head of fluid; g. equalizing the pressure from the formation by the hydrostatic head of fluid in the tubing string; h. removing the combination valve from the landing receptacle; i. continuing the remedial workover operations.
e. creating a pressure to the top of the combination valve until a predetermined amount of pressure has been reached so that the selective dis-attachment means is actuated;
f. pumping a fluid through the combination valve and down the tubing string to create a hydrostatic head of fluid;
g. equalizing the pressure from the formation by the hydrostatic head of fluid in the tubing string;
h. removing the combination valve from the landing receptacle;
i. continuing the remedial workover operations.
The method of claim 11, further comprising the steps of: e. creating a pressure to the top of the plug until a predetermined amount of pressure has been reached so that the selective dis-attachment means is actuated; f. removing the combination valve from the landing receptacle utilizing the lubricator; g. continuing the remedial workover operations.
e. creating a pressure to the top of the plug until a predetermined amount of pressure has been reached so that the selective dis-attachment means is actuated;
f. removing the combination valve from the landing receptacle utilizing the lubricator;
g. continuing the remedial workover operations.
Ref US20180003002A1: Claims:
A method of sealing a well bore production tubing string at a well tubing head using a test-port pressure actuated sealing apparatus installed in-line with the well bole production tubing string.
The method of sealing the well bore production tubing string of claim 1 wherein the method further comprises the following steps: adapting an improved tubing hanger to the well tubing head, the improved tubing hanger having the test-port pressure actuated sealing apparatus installed in-line with the well bore production tubing string, the well tubing head having a standard test-port in communication with the improved tubing hanger, utilizing a void space created between the improved tubing hanger and the well tubing head, the void space having fluid communication with the standard test-port and further fluid communication with the test-port pressure actuated sealing apparatus, applying introduced pressure through the standard test-port, building the introduced pressure within the void space, overcoming well pressure pressing up from the well bore production tubing string with the introduced pressure applied through the standard test-port and transferred via fluid communication through the void space to the test-port pressure actuated sealing apparatus, and actuating the test-port pressure actuated sealing apparatus to seal the well bore production tubing string.
adapting an improved tubing hanger to the well tubing head, the improved tubing hanger having the test-port pressure actuated sealing apparatus installed in-line with the well bore production tubing string, the well tubing head having a standard test-port in communication with the improved tubing hanger,
the improved tubing hanger having the test-port pressure actuated sealing apparatus installed in-line with the well bore production tubing string,
the test-port pressure actuated sealing apparatus installed in-line with the well bore production tubing string,
the well tubing head having a standard test-port in communication with the improved tubing hanger,
utilizing a void space created between the improved tubing hanger and the well tubing head, the void space having fluid communication with the standard test-port and further fluid communication with the test-port pressure actuated sealing apparatus,
the void space having fluid communication with the standard test-port and further fluid communication with the test-port pressure actuated sealing apparatus,
applying introduced pressure through the standard test-port,
building the introduced pressure within the void space,
overcoming well pressure pressing up from the well bore production tubing string with the introduced pressure applied through the standard test-port and transferred via fluid communication through the void space to the test-port pressure actuated sealing apparatus, and
actuating the test-port pressure actuated sealing apparatus to seal the well bore production tubing string.
The method of claim 2 wherein the test-port pressure actuated sealing apparatus of the improved tubing hanger further comprises: a body, a transfer component, an actuating mechanism, and a sealing valve, wherein the body houses the transfer component, the actuating mechanism, and the sealing valve.
a transfer component,
an actuating mechanism, and
a sealing valve,
wherein the body houses the transfer component, the actuating mechanism, and the sealing valve.
The method of claim 3 wherein the body is in fluid communication with the test-port.
The method of claim 3 wherein the introduced pressure within the void space displaces the transfer component.
The method of claim 5 wherein the transfer component initiates the actuating mechanism.
The method of claim 6 wherein the actuating mechanism moves the sealing valve.
The test-port pressure actuated sealing apparatus of claim 3 wherein the body is adapted to sealably join with the well tubing head.
The test-port pressure actuated sealing apparatus of claim 3 wherein: the transfer component is comprised of a ring piston, the sealing valve is comprised of a gate valve, the actuating mechanism is further comprised of a gate assembly.
the transfer component is comprised of a ring piston,
the sealing valve is comprised of a gate valve,
the actuating mechanism is further comprised of a gate assembly.
The test-port pressure actuated sealing apparatus of claim 9 wherein the gate assembly further comprises a spring.
The test-port pressure actuated sealing apparatus of claim 3 wherein the body further comprises at least two members further comprising a lower body and an upper body.
The at least two members of claim 11
[Truncated to input limit]