Lessons Learned Using a Next Generation Active Sealing Device for Deepwater MPD Operations

2021 ◽  
Author(s):  
Austin Johnson ◽  
Saravanan Sundaramoorthy ◽  
Kareem Ameen ◽  
Jess Nichols ◽  
Alex MacGregor ◽  
...  
Keyword(s):  
Black Sea ◽  
System Performance ◽  
Network Architecture ◽  
Control Device ◽  
Lessons Learned ◽  
The Black Sea ◽  
First Year ◽  
Test Procedures ◽  
Novel Approach ◽  
Sealing Device

Abstract This paper shares results from the first year of deepwater operations using an active sealing device purpose built for deepwater Managed Pressure Drilling (MPD). The active sealing device is a clean-sheet design approach. The first use of the system was performed in a narrow margin deepwater well in the Black Sea with subsequent wells in the Gulf of Mexico. This paper shares lessons learned from first year of operations. This paper discusses field operations, lessons learned, and post run evaluation of system performance. An overview of the design introduces system elements and briefly discusses system testing measures taken prior to field deployment. An overview of operations from the first year is provided, highlighting lessons learned, action items taken, and solutions implemented between wells. Analysis of the link between the testing and field results demonstrates the novel approach to testing and validity of assumptions made during the testing phase. Furthermore, methods of evaluating seal performance are discussed. The paper shares conclusions from the first year of active sealing device deployment. A non-rotating seal sleeve element design eliminates multiple high-wear rotating control device (RCD) components such as bearings and rotary seal as well as their associated failure modes.Redundant, active seal elements ensure wellbore seal quality throughout the seal assembly life.Active seal condition monitoring alerts the rig crew prior to failure to replace the seal assembly.Multi-modal seal control provides crew methods to reach total depth in contingency mode.Full-scale simulated drilling testing included the use of client equipment prior to first use.Testing procedures were designed to simulate drilling to mirror system use in a live well.First MPD well completed in 2019 in the Black Sea with subsequent wells in the Gulf of Mexico.Lessons learned from operations to applied in continuous improvement program.Novel approaches to assessing performance have been developed in order to provide consistent metrics.Learnings have been applied in subsequent wells to improve technology transfer to drilling contractors. The paper discusses other aspects of the program such as drilling contractor ownership vs. use of third (3rd) party systems, integration of the MPD equipment into the rig, and network architecture. Further, an algorithm has been developed to analyze system performance from electronic drilling recorder data to better characterize the effect of usage patterns of seal wear. These data demonstrate the validity of assumptions made during the development of the test procedures.

Fracture Hits Mitigated Successfully in High-Pressure Stimulation Offshore Black Sea

2021 ◽  
Vol 73 (06) ◽  
pp. 51-52
Author(s):  
Judy Feder
Keyword(s):  
High Pressure ◽  
Black Sea ◽  
Lessons Learned ◽  
The Black Sea ◽  
Reservoir Pressure ◽  
Fracture Simulation ◽  
Multi Stage ◽  
Geomechanical Analysis ◽  
Pressure Depletion ◽  
Fracture Growth

This article, written by JPT Technology Editor Judy Feder, contains highlights of paper SPE 201422, “Successful Mitigation of Fracture Hits in High-Pressure Stimulation Using Bottomhole Gauges and an Optimized Engineering Design, Offshore Black Sea,” by Gabrijel Grubac, SPE, Radu Patrascu, and Peter Janiczek, SPE, OMV, et al., prepared for the 2020 SPE Annual Technical Conference and Exhibition, originally scheduled to be held in Denver, Colorado, 5–7 October. The paper has not been peer reviewed. This paper presents a case study of fracture interaction mitigation in a multistage horizontal stimulation of an offshore Black Sea well. The authors discuss a multifaceted approach in applying lessons learned and pre-job geomechanical analysis of depletion-induced stress differential and its effects on fracture interactions. Intrastage fracture interference presents unique challenges that typically are managed on a case-by-case basis. This study aims to present critical analyses that are paramount to planning stimulation treatments in highly depleted segments and reservoirs with close-proximity wells. Project Background The operating company began a field redevelopment project in 2013 for a field in the Black Sea that was already producing from horizontal wells with multi-staged fractured wells. The project comprises three treatment wells (A, B, and C) and seven offset wells (1 through 7). Because of time-critical operations and related costs, the original treatment wells and sidetracks (5,000-m-long measured depth horizontals) were completed with multistage stimulation sleeves and were operated by a ball-drop system from the surface. Infill drilling was implemented with the newly added sidetracks because of the maturity of the field and the desire to optimize the hydrocarbon drainage process. Well C was the first infill well. A multi stage fracturing campaign for Well C began in 2015. The complete paper presents a detailed discussion of issues—including strong fracture communication—identified, and mitigation steps attempted, during the infill project. Various simulation methods and depletion models that were tried and later rejected are also discussed. Several investigations were begun into how to predict, and subsequently avoid, fracture-driven interactions. Industry practice with huge quantities of water injection in the offset wells was not feasible because of the already-low economics of the treatment wells. A half-iterative process between reservoir modeling and fracture modeling was begun, and an actual reservoir pressure-depletion map was created on a sector basis. Similarly, the fractures were simulated using a grid-oriented fracture simulator in full 3D. Using this approach, it was also possible to match previously identified communication between wells and highly nonsymmetric fracture growth. The initial plan for the recent multi-stage fracturing campaign was to drill all wells closer in time to reduce localized depletion and to allow initial fractures from offset wells to act as a stress barrier to mitigate fracture growth in the direction of those wells. A matched reservoir and geomechanical model was used for the fracture simulation, and the actual depletion map for different time regimes was introduced. It was decided to redesign the fracture treatments and to shut in the offset wells 36 hours before the treatment, and to keep them shut in during the entire stimulation operation. At that point, it became clear that reservoir pressure depletion was one of the main causes of communication and also impeded optimal fracture geometries and hydrocarbon recovery.

Rotating Control Device Sealing Element Customization for Ultra-Deepwater Gulf of Mexico

2021 ◽  
Author(s):  
Blaine Dow ◽  
Dexter Pazziuagan ◽  
Ken Vaczi ◽  
Chima Chima ◽  
Jason Guidry ◽  
...  
Keyword(s):  
Gulf Of Mexico ◽  
Drill Pipe ◽  
Cost Effective ◽  
Control Device ◽  
Drill String ◽  
Lessons Learned ◽  
Test Procedures ◽  
Element Analysis ◽  
Effective Manner ◽  
Tool Joint

Abstract As the Managed Pressure Drilling (MPD) systems for deepwater drilling rigs mature, operators are applying the technology on more complex prospects. Wells are encountering higher pressures in deeper water depths, pushing against the boundaries of technical limits not previously encountered. A prospect in the US Gulf of Mexico required drilling to measured depths exceeding 31000 feet in water deepwater. Under such demanding depth, a non-typical drillstring was required to manage the tensile loading. Typical drill pipe connections on 6 5/8" S-135 tool joints are 8.5" diameter. This drill string would require V-150 landing string, with a 6 5/8" FH tool joint diameter of 8.875". Hard banding would bring the tool joint nominal OD above 9". The depth of the well and planned string RPM presented risk of casing wear, therefore drillpipe protectors would also be required. The depth of the reservoir and size of the drillstring meant pipe would need to be stripped out of the well with up to 900 psi backpressure in order to maintain constant bottom hole pressure. All well challenges were used to determine design specifications for a custom sealing element. The scope of work was to design, validate through finite element analysis, then validate in a test fixture per API16RCD test procedures. On conclusion of the product validation, a land test rig trial, with mock-up of the planned system, including dual sealing elements in the Rotating Control Device (RCD), the required non-rotating drill pipe protectors on the planned drillpipe, was executed. The development schedule from start to finish was compressed to less than 6 months also, targeting completion ahead of the rig's drilling program. This paper will recount the various phases of the design-build-validate-test effort that went into resolving these technical limits. It will conclude with field results and lessons learned from first deployment. As operators pursue more challenging deepwater wells, this systematic approach, through alignment of the operator, drilling contractor and MPD technology company, serves as a model to expand the operating envelope of drilling systems, improving safe performance in a cost-effective manner.

MÖSSBAUER AND CHEMICAL ANALYSES OF SOME SEDIMENTS FROM THE ROMANIAN SHORE OF THE BLACK SEA

1979 ◽  
Vol 40 (C2) ◽  
pp. C2-445-C2-448
Author(s):  
D. Barb ◽  
L. Diamandescu ◽  
M. Morariu ◽  
I. I. Georgescu
Keyword(s):  
Black Sea ◽  
The Black Sea ◽  
Chemical Analyses

Modeling of ecological conditions in the Euxine Basin in the Sarmatian and Maeotian by methods of diatom analysis

2019 ◽  
pp. 257-261
Author(s):  
Eleonora P. Radionova
Keyword(s):  
Black Sea ◽  
Late Miocene ◽  
The Black Sea ◽  
Subtidal Zone ◽  
Diatom Analysis ◽  
Diatom Flora ◽  
North West ◽  
Ecological Conditions ◽  
The North

The associations and ecological conditions of the existence of modern diatoms of the North-West (Pridneprovsky), Prikerchensky and Eastern regions of the subtidal zone of the Black Sea are considered. Based on the unity of the composition of the Present and Sarmatian-Meotian diatom flora, an attempt has been made to model some of the ecological c situation of the Late Miocene Euxinian basin.

Subsatellite observations of the fundamental bio-optical parameters of the Black Sea (new approach)

2002 ◽  
Vol 8 (2-3) ◽  
pp. 231-238
Author(s):  
G.K. Korotaev ◽  
◽  
M.E. Li ◽  
G.A. Tolkachenko ◽  
◽  
...  
Keyword(s):  
Black Sea ◽  
The Black Sea ◽  
Optical Parameters ◽  
New Approach

Significance of Mineralogical and Lithologic-Petrographical Rank in the Ranking of Geological Information

2020 ◽  
Vol 42 (4) ◽  
pp. 33-49
Author(s):  
O.V. CHEPIZHKO ◽  
V.V. YANKO ◽  
V.M. KADURIN ◽  
I.M. NAUMKO ◽  
S.M. SHATALIN
Keyword(s):  
Fluid Flow ◽  
Black Sea ◽  
Bottom Sediments ◽  
Oil And Gas ◽  
Sedimentary Cover ◽  
Geochemical Characteristics ◽  
The Black Sea ◽  
Flow Parameters ◽  
Geochemical Parameters ◽  
Geological Information

For the first time the importance of mineralogical and lithological-petrographical ranks in the line of geological information ranks is substantiated for implementation of long-term forecasts, standard and non-standard approaches to research of physical and geochemical parameters as a basis of creation of complex system of forecast criteria and prospecting indicators of hydrocarbons within the sedimentary cover of Black sea based on the theory of global fluid-flows derivation. These criteria have different sensitivity to the object (hydrocarbon deposits) and are therefore ranked. The ranking determined the following parameters: 1) seismic data within the object, obtained by the method of deep seismic sounding, RWM SDP; 2) parameters of tectono-geodynamic structures; 3) the main characteristics of sedimentary cover and bedrock; 4) geochemical characteristics; 5) parameters of mineral complexes and fluid inclusions in mineral neoformations; 6) the value of the distribution of meiobenthos. Based on modern views of oil and gas geology, structural-tectonic and lithological-facies criteria are among the main ones. The study of the mineralogical component of sediments is made with using mineralogical, thermobarogeochemical and X-ray spectral methods. Fixation of anomalies of fluid flow at the bottom of the Black Sea as to the distribution of abiotic parameters in order to assess the prospects of oil and gas is determined by structural and tectonic features and high permeability of fluid flow; parameters of mineral complexes (minerals, facies) and genetic connections; heterogeneity of geochemical characteristics of bottom sediments; the presence of hydrocarbon inclusions in authigenic minerals of bottom sediments.

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