AbstractOperators in the Permian Basin have been performing two stage cementing operations on their casing strings for decades utilizing conventional diverter tool technology, often in combination with casing annulus packers.Over time, issues with legacy diverter tools (DV) have been identified and solutions sought. These issues range from longer than desired time to drill-out the DV tool, reluctance to drill-out a DV tool with a directional assembly due to drill bit dulling and premature drilling motor/MWD failures, damage to the DV tool while drilling causing leaks and remediation, and an inability to pressure test the whole casing string after cementing. A development effort was made to eliminate these issues. The Hydraulic Port Collar (HPC) was designed and extensive qualification/testing of the HPC design was performed prior to field deployment. Running procedures were written and revised in consultation with a variety of operators. Several wells were identified for field trials. The wells were selected based on the operator’s desire to eliminate a DV tool drill-out. The wells had complex directional plans that required high bend drilling motors resulting in the operator’s reluctance to drill-out conventional DV tools with the curve BHA’s.The hydraulic port collar functioned as designed on all field trials. Pressure readings from the cement trucks confirmed the tools opened within the calculated pressures and closed and sheared out within the calculated pressures. Full communication of compressed volume, from the float collar to surface was achieved, allowing the operator to perform a full string casing test. The wiper plug was mechanically confirmed as released from the HPC and subsequently pushed to bottom and drilled up when the shoe track was drilled out. Utilizing curve BHA’s with 2.12° to 2.38° bend motors, all wells were drilled and landed in the drilling window with one curve BHA run. As a result, dedicated DV tool drill-out runs were eliminated, no unusual damage or dulling of the curve BHA was observed and no post drill-out damage/leaks at the HPC were experienced. A review of the field trials showed efficiency gains up to 40% when compared to previous operations where legacy DV tools had been deployed. These trials confirm that the novel Hydraulic Port Collar can increase operator efficiency in wells that require two stage cementing operations.This paper will document case histories and lessons learn to date.

2022-12-14·Day 1 Wed, December 14, 2022

Successful Subsea Reentry Well Abandonments with Coiled Tubing Deployed from a Multiservice Vessel in the Gulf of Mexico

作者: Bounds, Nathan ; Dhorje, Dhananjay ; Shier, Scot ; Rudnik, Alexander ; Norton, Thomas ; Antunes, Arthur Da Silva ; Cartie, Bryan ; Adams, Edward ; LeJeune, Ricky ; Garber, Jaret Michael

AbstractTwo subsea exploration wells located in the Gulf of Mexico at water depths of approximately 1,800 ft had remained temporarily abandoned while waiting on further decision since 1997–1998. When the current operator decided to permanently abandon those wells, the procedure called for a reentry by drilling out cement plugs set below the mudline inside the 9⅝-in. outside diameter (OD), 8.535-in. minimum inside diameter (ID), casing and permanently abandoning the wells by isolating the annular space that communicated with the open hole and extended to the mudline. Operations had to be completed rigless using an intervention riser system (IRS) with a 6.31-in. drift ID.A system incorporating capabilities normally associated with costly rigs was developed. It included a 2⅜-in. OD coiled tubing (CT) deployed from a multiservice vessel. To overcome challenges associated with milling cement using undergauge mills and possible pressurized gas trapped beneath the plugs, a two-step approach leveraging a 4.5-in. OD pilot mill bottomhole assembly (BHA) followed by a 5.9-in. OD mill and 8.3-in. OD underreamer BHA was implemented. A biopolymer-based milling fluid was selected to increase the solids carrying capacity and facilitate hole cleaning at low annular velocities (limited by friction losses through the CT workstring). A fluid management system provided a closed-loop solution for controlling fluid properties while removing solids from the system. The annular spaces were isolated by using a combination of decentered casing perforations, inflatable cement retainers, and latex cement systems. The cement was optimized to reduce recipe variations for different placement depths and bottomhole static temperatures.All cement plugs were successfully drilled out and the milling fluid provided good hole cleaning performance without any stuck pipe events. All fluids and tools performed as expected. The 9⅝-in. × 13⅜-in., 16-in. × 13⅜-in., and 20-in. × 16-in. annuli were isolated, and permanent abandonments were completed in accordance with the applicable regulations.The project required multiple service lines to work synergistically. Careful planning and seamless communication between all parties involved were key to ensuring optimal efficiency and safety while reducing the overall operational expenditures. The collaboration instilled between all the project stakeholders delivered incident-free operations at the lowest total operational cost, which came below the authorization for expenditures of each well as compared to rig-based abandonments.Although reentry well abandonments are not new to the industry, there is no history of such services performed inside large casings with CT from a multiservice vessel through an IRS with minimum ID restriction. This study details the engineered solutions and methodologies that enabled successful operations. It also discusses the project parameters, examines the operations, and proposes the lessons learned to serve as a benchmark for future such projects.

2017-10-09·SPE Annual Technical Conference and Exhibition

Enhancing Cement Integrity in Steam Injection Applications with High Temp Swellable Technology

作者: Clark, Travis ; Hance, Derek ; Davis, Tim

AbstractA critical design component on any steam injection project is to ensure steam containment. Loss of steam containment is not only a safety hazard, but also leads to poor well performance. Large changes in temperature have always been challenging to maintaining cement integrity not only during temperature ramp up, but certainly over the life of the well. Using high temperature swellable technology as part of the design for containment has proven to be highly effective.In the design of a well, there are multiple casing strings, each with containment criteria and challenges. Challenges typically are due to difficulties in placing the cement and uncertainties on borehole shape. For years swellable packers have been used in conjunction with cement to overcome these challenges where cement alone has a low probability of providing successful containment. These challenges become more difficult in steam applications. Advancements in packer design and elastomer technology has led to the development of packers that can be run in casing designs which will encounter temperature up to 575°F (302°C). During the well design, critical containment areas are reviewed and consideration for the inclusion of a high temperature swellable packer is performed.An operator of a cyclical steam injection project typically has seen steam at surface within days or weeks after initial heat up of the well. This results in additional steps to operate, maintain, and report on the well. High temperature swellable packers were piloted over a selected number of wells. It was found that wellhead pressure on cemented annuli was eliminated or significantly reduced after the first cycle of steam injection. The practice of including the packers now is used on every well and success is still being observed after multiple cycles of temperature. This reduces safety hazards as well as improve performance of the wells.

100 项与 TAM International 相关的药物交易

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