Nguyen, Dzu (BP) | Macleod, Innis (BP) | Taylor, Donald (BP) | Murray, Laurence (BP) | Zavyalov, Denis (BP) | Booth, Dave (Fircroft Consultant, former BP) | Robertson, Neil (Halliburton) | Smith, Robert (Halliburton) | Joubran, Jonathon (Halliburton) | Allen, Clifford (Halliburton) | Shafei, Sharil Mohd (Halliburton)
The multiple zone water injection project (MZWIP) was initiated to deliver the following key objectives: deliver zonal injection with conformance control and reliable sand management across the major layered sands of the Balakhany unconsolidated reservoirs in the BP operated Azeri-Chirag-Gunashli (ACG) fields in Azerbaijan sector of the Caspian Sea.
Three years after MZWIP implementation, six wells with a total of 14 zones are injecting at required rates with zonal rate live-reporting. To achieve this multizone injection facility, the requirement for a standard ACG sand-control injector design was discounted and a non-standard sand management control technique developed using a cased & perforated (C&P) and downhole flow-control system (DHFC). During this program, BP ACG has successfully installed the world's first 10kpsi three-zone inline variable-choke DHFC wells with distributed temperature sensors (DTS) across all target injection zones.
The choking DHFC provides flexibility in operations and delivers the right rates to the right zones. The DTS provides conformance surveillance, fracture assessment, caprock integrity and sand ingress monitoring capability. A customized topside logic control system provides an automatic shutin of interval control valves (ICVs) during planned or unplanned shutins to stop crossflow and sand ingress and is the primary method of effectively managing sanded annuli.
The development of this MZWI solution has significantly changed the Balakhany development plan and has been quickly expanded across five ACG platforms. Accessing 2nd and 3rd zones in the same wellbore, this C&P DHFC well design is accelerating major oil volumes and will significantly reduce future development costs, maximizing wellbore utility in a slot-constrained platform.
Albertini, Cristian (Eni Spa) | Bigoni, Francesco (Eni Spa) | Francesconi, Arrigo (Eni Spa) | Lazzeri, Riccardo (Eni Spa) | Vercellino, Alberto (Eni Spa) | Borromeo, Ornella (Eni Spa) | Gabellone, Tatyana (Eni Spa) | Consonni, Alberto (Eni Spa) | Geloni, Claudio (Eni Spa)
The reservoir quality of Karachaganak Carbonates Field results significantly affected by diagenetic processes. In particular, the replacive dolomitization affects porosity, permeability and irreducible water saturation while the precipitation of anhydrite reduces both porosity and permeability. Such impacting processes were therefore analysed and described in the reservoir 3D Model following geologically consistent rules that honour well data.
The field scale diagenetic study was performed following five steps:
Core data studies Lithological logs analysis Hydrological processes identification Hydrological processes reactive transport simulations 3D Lithological model building
Core data studies
Lithological logs analysis
Hydrological processes identification
Hydrological processes reactive transport simulations
3D Lithological model building
The dolomite distribution, estimated from the lithological log analysis and cores data, results mainly confined on the flanks of the paleo-high. This distribution was endorsed by the results of 3D field scale reactive transport modelling related to Kohout geothermal convection mechanism acting in the shallow burial of the carbonate paleo-high at each stratigraphic unit. The final lithological 3D Model was built consistently with this hydrological process calibrated with well data used as verification data set in the stochastic simulations.
The anhydrite distribution, estimated from lithological log analysis and cores data, is, generally, present in a few percentage of volume and, mainly, in the upper section of the reservoir (less than 250 m, below the bottom of the overlaying Kungurian evaporites). This anhydrite was related to diffuse downward percolation of the Kungurian brine and, marginally, to dolomitization. The occurrence of higher concentration of anhydrite was also locally observed but generally connected to fracture infill and, sometimes, also in the deeper section of the reservoir. These events were related to brine percolation exploiting a network of syn-depositional fractures, particularly along the flanks of the carbonate bank (Neptunian dykes). Such hydrological processes was endorsed by 2D reactive transport modelling. In fact, the anhydrite infilling fractures may have a significant impact on the reservoir flow path and therefore a workflow for identification of these Neptunian dykes was applied, based on seismic attributes (Continuity and Curvatures) according to the Eni proprietary workflow utilized for the identification of sub-seismic discontinuities (Tfrac-Sibilla).
The so estimated dolomite distribution represents about the 15% of the lithology at field scale but up to the 60% on the flanks of the carbonate build-up, marginal areas investigated by very few wells but impacting on about the 30% of the field total GBV. Accordingly, the petrophysical characteristics of the field flanks result affected, in the 3D Reservoir Model, by the presence of dolomite, i.e. increased porosity, permeability and irreducible water saturation. Moreover, the identification of the sub-seismic discontinuities filled by anhydrite allows a better description of the permeability baffles affecting the 3D model flow paths.
BP and partners have sanctioned the Azeri Central East project, the next stage of development of the giant Azeri-Chirag-Deepwater Gunashli oilfield complex in the Azerbaijan sector of the Caspian Sea. RDS, a KCA Deutag division, and Kavin Engineering and Services entered into a strategic alliance to jointly pursue design and engineering projects across the upstream and midstream oil and gas market. Last month, KCA Deutag agreed to form a joint venture with SOCAR.
BP and partners have sanctioned the Azeri Central East project, the next stage of development of the giant Azeri-Chirag-Deepwater Gunashli oilfield complex in the Azerbaijan sector of the Caspian Sea. RDS, a KCA Deutag division, and Kavin Engineering and Services entered into a strategic alliance to jointly pursue design and engineering projects across the upstream and midstream oil and gas market. Last month, KCA Deutag agreed to form a joint venture with SOCAR. Baku Shipyard completed the sea trials of BP's subsea construction vessel Khankendi, which is being constructed for the Shah Deniz Stage 2 project.
Phase 1 production from the deepwater US Gulf of Mexico field is expected to reach 30,000 BOPD. The field contains an estimated 5 billion bbl of oil in place. After suffering major setbacks, Chevron’s massive Big Foot project finally achieved first oil last November in the US Gulf of Mexico. With the setbacks in the rear-view mirror, project personnel spoke about the challenges. BP and partners have sanctioned the Azeri Central East project, the next stage of development of the giant Azeri-Chirag-Deepwater Gunashli oilfield complex in the Azerbaijan sector of the Caspian Sea.
The E&P company said that a reduction in its interests for projects off the coast of the West African nations should still happen by the end of this year. This includes the large Greater Tortue Ahmeyim LNG project, which is set to start up in 2022. Drones are becoming an important tool for energy companies looking to improve on-site safety and operational efficiencies, and the industry is looking for the best way to maximize their value. What are some the challenges in getting these programs off the ground? The criticality of above-water riser hull piping requires frequent inspections.
Upon completion, the FPSO will be the first permanently fiber rope-moored offshore facility in the Mediterranean, processing the reservoir fluids and export sales gas from the Karish and Tanin gas fields offshore Israel. At nearly 3,000 tonnes, the company said its lift of an FPSO module was one of the heaviest land-based crane lifts ever performed. ALE was contracted to lift six modules for Total’s FPSO module integration project in Nigeria. The Neptune-operated project is on track to start drilling later this year, with first oil scheduled for the end of 2020. The Norwegian North Sea field is expected to produce 30,000 BOE/D at its peak.
In a $60 to $70 oil environment, the subsea market is poised to grow around 7% annually up to 2025. But a significant portion of this activity is at risk if the price of Brent crude falls to $50 per barrel. The subsea operations company said its most recent campaign is the first fully unmanned offshore pipeline inspection completed “over the horizon,” surveying up to 100 km from the shore. One of the largest industrial projects in the UK in recent years, Mariner marks Equinor’s first operated field on the UK Continental Shelf. It is expected to produce 70,000 BOPD at peak rates.
The entrepreneurial ecosystem and the oil and gas industry are not a perfect match, but the industry has made strides in recent years to attract the startups developing innovative technologies that could usher it into a new era. How are companies bridging the gap? The deal sees H2O Midstream increase its produced water gathering network to more than 435,000 B/D of disposal capacity and 190 total miles of pipeline. The Permian water midstream company will add more than 40,000 B/D of recycling capacity with the option to double that capacity over time. The transaction is planned to be structured as a spin-off of TechnipFMC’s onshore/offshore segment to create SpinCo and RemainCo. The separation is expected to be completed in the first half of 2020. Calgary-based Pembina Pipeline Corp. has entered into agreements to acquire Kinder Morgan Canada Ltd. and the US portion of the Cochin Pipeline system from Kinder Morgan for a total purchase price of approximately $4.35 billion.