Murphy Oil to Buy Deepwater US Gulf Assets for up to $1.625 Billion The El Dorado, Arkansas-based Murphy has quickly found a home for some of the cash it will receive from the sale of its Malaysia business. The company has been rapidly expanding its US gulf footprint while simplifying its portfolio and targeting more oil. The pact, which builds on the firms’ current partnership on the Buckskin project, covers four Keathley Canyon blocks including the Leon and Moccasin discoveries. BP announced four discoveries in the Gulf of Mexico near existing platforms. It use advanced seismic imaging to identify resources in deepwater locations that can be developed cost effectively using platforms nearby.
Australia’s BHP Billiton and the recently acquired Anadarko Petroleum submitted the largest dollar totals of high bids in US Gulf of Mexico Lease Sale 253. Operator Talos Energy now believes Zama’s gross recoverable resource lies in the upper half of its pre-appraisal estimate of 400–800 million BOE. The consortium is working toward a 2020 final investment decision on the project. The deal consists of stakes in nine shallow-water producing fields covering 108,000 gross acres in 10–50 m of water. The new well control rule is evidence that memories of the Macondo blowout remain a powerful force for caution.
The firms are now partners on multiple blocks in the North Argentina Basin. Australia’s BHP Billiton and the recently acquired Anadarko Petroleum submitted the largest dollar totals of high bids in US Gulf of Mexico Lease Sale 253. Production from the Hibernia platform was shut down again on 17 August after its second oil spill in a month, while Husky Energy began to ramp up output from the White Rose field following the largest-ever spill off Canada’s easternmost province. The discovery marks London-based Tullow’s first operated contribution to a long list of discoveries since 2015 in the emerging petroleum province. Anchored by the Khaleesi-Mormont and Samurai fields, the King’s Quay FPS will receive and process up to 80,000 B/D of crude oil.
Latest News are articles brought to you online only and have not been published in an issue of JPT. The well will immediately be brought on production and is expected to flow at more than 100 MMscf/D of gas and 3,000 B/D of associated condensate, the company said. The $5.6-billion deal includes the Prudhoe Bay field and the Trans Alaska Pipeline and vaults Hilcorp to be the second-largest Alaska producer and reserves holder, behind only ConocoPhillips. The shale sector is studying the results of a 23-well experiment in the southeastern corner of New Mexico to learn what the wider implications might be. The shale sector is making moves to consolidate amid investor pressure to increase cash flow. This deal will form the second-largest producer in Colorado’s DJ Basin.
The pact, which builds on the firms’ current partnership on the Buckskin project, covers four Keathley Canyon blocks including the Leon and Moccasin discoveries. The explorer has so far encountered 400 ft of reservoir pay zone in an area where it has three other producing fields. Conventional oil and gas discovered resources in 2019 are on pace to rise 30% from last year and reach their highest level since the beginning of the industry downturn. Here, a recap of the first quarter's 15 biggest oil and gas discoveries, which altogether are propelling the increase. Colombia now counts Repsol, ExxonMobil, Shell, and Noble Energy as companies committed to exploration in its portion of the Caribbean Sea.
The $5.6-billion deal includes the Prudhoe Bay field and the Trans Alaska Pipeline and vaults Hilcorp to be the second-largest Alaska producer and reserves holder, behind only ConocoPhillips. The shale sector is making moves to consolidate amid investor pressure to increase cash flow. This deal will form the second-largest producer in Colorado’s DJ Basin. The firms are now partners on multiple blocks in the North Argentina Basin. Australia’s BHP Billiton and the recently acquired Anadarko Petroleum submitted the largest dollar totals of high bids in US Gulf of Mexico Lease Sale 253.
Africa (Sub-Sahara) Eni Congo discovered oil at its Minsala Marine 1 well offshore the Republic of the Congo in Marine XII Block 12 km from the operator's recent Nené Marine discovery. Minsala intersected 420 m of gross pay and encountered light oil in a Lower Cretaceous presalt sequence. The well reached a total depth of 3700 m. Eni (65%) is operator, with state-owned partner SNPC 25%), and New Age (African Global Energy) Limited (10%). SOCO EPC's Lindongo X Marine 101 Well (LXM-101)--located offshore the Republic of Congo in Marine XI Block--encountered oil in a clastic sequence of the Djeno sands, with early log interpretation indicating approximately 50 m of gross pay.
Surface wave is a common kind of interference wave in land-based seismic acquisition. Many methods have been used to suppress the surface wave, each of them is partially effective. None of the transforms are ideal, the result is that the surface wave not be suppressed completely or the reflect wave is damaged. In view of this problem, an innovative hybrid method of surface wave suppression based on Shearlet transform and Time-Time (TT) transform is proposed in this paper. First, effective reflection wave and surface wave which mainly distributes in low frequency and high-wavenumber can be separated by taking advantage of the excellent localized property of high-scale basis function and the property of directional representation of Shearlet transform; second, making use of excellent identification capability to low frequency of TT transform, most of surface wave component of low frequency and low wavenumber can be suppressed by using the time-variant filtering in TT domain; finally, according to the more accurate effective signal extracted by the Shearlet transform, an adaptive time-variant and space-variant filter is designed to remove the residual surface wave further, then transform it back to time domain, we can get the final data without surface wave. Applying this method to synthetical and real field data sets and comparing to FK filtering and TT filtering method, the result shows that the method in this paper can suppress surface wave, at the same time also maintain the amplitude and phase information of reflection wave.
Li, Zhina (China University of Petroleum) | Li, Zhenchun (China University of Petroleum) | Wang, Peng (China University of Petroleum) | Zhang, Min (China University of Petroleum) | Ren, Dengzhen (China University of Petroleum)
In borehole seismic, wavefield separation is an important issue which has great influence on data imaging. In this paper, we present a modified linear Radon transform to deal with the upgoing and downgoing wavefield separation. On the basis of the frequency-domain linear Radon transform, this method is implemented by introducing a new variable λ and the reflection wavefield separation is done in λ - f domain instead of p – f? domain. What’more, the theory of high resolution Radon transform is introduced. With the application of this method, significant improvement in accuracy and computational efficiency can be obtained in wavefield separation. Examples from the synthetic data and real borehole seismic data (both VSP data and cross-well seismic data) verify this method is feasible and valid.
As an industry, we are still in the early stages of the learning curve for shale gas drilling although many shale gas wells have been drilled in recent years. Data from over one thousand wells drilled in the Maverick basin since 2003 were retrieved from an internal drilling database. Among them are over two hundred horizontal wells from the Eagle Ford shale play drilled by 31 different operators between 2008 and early 2011. The analyses of drilling performance data of these horizontal wells offer the establishment of general practice guidelines and recognition of opportunities for improvement in Eagle Ford shale drilling.
Oil-based drilling fluid, or "mud?? (OBM) is a typical drilling fluid type currently used to drill from the surface casing shoe to the total depth (TD) in the Eagle Ford shale play. However, water-based mud (WBM) has also been used since the development of the Eagle Ford shale play. A comparative analysis was performed between oil-based and water-based drilling fluids to assess their performances and to identify the key challenges and potential areas for improvement when drilling in the Eagle Ford shale. The analyses included mud chemistry, drilling performance, mud weight and well architectures such as bit sizes, casing sizes and depths of the casing shoe, as well as lateral length. A statistical analysis (P10, P50, and P90) was also performed to evaluate industry-wide drilling performance such as drilling days for wells of various depths. Comparisons were made among different drilling fluid types and different operating companies.
The statistical analysis shows that although overall performance of water-based drilling fluids lags behind that of oil-base fluids in Eagle Ford shale drilling, a certain WBM system shows promising performance close to that of oil-based drilling fluids. The analysis shows that there is a general trend of decreased drilling days per footage over time and a large variation in total drilling days for similar well depths and trajectories. This indicates that although the drilling industry as a whole has improved drilling in the Eagle Ford shale over the years, there is still a large opportunity for improvement. One interesting finding is that some operators can drill wells in fewer days than the industry average even though their drilling fluid cost is slightly more expensive than the industry average. As a result of reduced drilling time, their overall drilling costs are reduced.
Lab test results with different fluid types show that the failure mechanism and shale-fluid interaction of the Eagle Ford shale is different from dispersion or swelling which are typical of traditional shales. The analyses and results of this study on drilling performance data provide lessons learned and general guidelines for current drilling practices and opportunities for improvement such as drilling fluid selections, mud weight, and well architectures in the Eagle Ford shale play.