Yamalo-Nenets Autonomous Okrug

Maximizing Recovery and Reducing Well Cost Using Herringbone Multilateral Horizontal Well Drilling and Completion Technology

Zhang, Xiaocheng (CNOOC China Limited, TianJin Branch) | Xie, Tao (State Key Laboratory Offshore Oil Exploitation CNOOC China Limited) | Huo, Hongbo (CNOOC China Limited, TianJin Branch) | He, Ruibing (State Key Laboratory Offshore Oil Exploitation CNOOC China Limited) | Lin, Hai (CNOOC China Limited, TianJin Branch) | Hou, Xinxin (State Key Laboratory Offshore Oil Exploitation CNOOC China Limited) | Xu, Dongsheng (CNOOC China Limited, TianJin Branch)

OnePetroMarch, 2023

Abstract With the in-depth development of Bohai Oilfield, China National Offshore Oil Corporation (CNOOC), the water cut of some old wells become too high to produce while nearby remaining recoverable reserves are still considerable. In order to maximize recovery and reduce well construction cost, herringbone multilateral horizontal well drilling and completion technology is employed to increase drainage area of single well and make full use of well slot and old wellbore. Considering the current development of oilfield and the geological characteristics of reservoir, the technical difficulties of herringbone multilateral horizontal well drilling and completion technology including high build-up rate, easy blockage of drilling tools in the sidetracking in open hole, easy collapse and instability of sandwich wall and high requirements for drilling fluid performance are analyzed and solved. This technology has been successfully applied in three wells with total 6 branches and the production of three wells is twice higher than that of conventional horizontal wells with no water cut, which fully verified the reliability of the branch well tools and the feasibility of the technology. Herringbone multilateral horizontal well drilling and completion technology provides a new idea for the treatment of low production and low efficiency wells in a sustainable way and will be widely promoted and applied in Bohai oilfield, which can also provide reference for other high water cut oilfields.

OnePetro

doi: 10.2118/214019-MS

SPE

SPE-214019-MS

Gas & Oil Technology Showcase and Conference

asia government, Bohai oilfield, china government, Directional Drilling, drilling operation, drilling sequence, fishbone, herringbone multilateral horizontal well drilling, requirement, reservoir, russia government, russian government, spe russian petroleum technology conference, Upstream Oil & Gas, wellbore

Country:

Asia > China (1.00)
Asia > Russia > Ural Federal District > Yamalo-Nenets Autonomous Okrug > Tazovksy District (0.28)
Asia > Russia > Siberian Federal District > Krasnoyarsk Krai (0.28)

Industry:

Energy > Oil & Gas > Upstream (1.00)
Government > Regional Government > Asia Government > China Government (0.55)

Oilfield Places:

Asia > Russia > Siberian Federal District > Krasnoyarsk Krai > Vankorskaya Area > Vankorskoye Field (0.99)
Asia > Russia > Siberian Federal District > Irkutsk Oblast > Kataganskiy District > East Siberian Basin > Nepa-Botuoba Basin > Verhnechonskoye Field (0.99)
Asia > Russia > Ural Federal District > Yamalo-Nenets Autonomous Okrug > Tazovksy District > West Siberian Basin > South Kara/Yamal Basin > Messoyakhskoye Field (0.97)
(2 more...)

SPE Disciplines: Well Drilling > Drilling Operations > Directional drilling (1.00)

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Integrated Engineering Solutions for Drilling Extended Reach Multilateral Wells with Lateral Sections More Than 2000 Meters with the Use of Mud Motor. Successful Experience in Tazovskoye Field

OnePetroMarch, 2023

Abstract Rotary Steerable Systems (RSS) are, in general, more efficient versus Positive Displacement Motors (PDM) when drilling the wells under complicated geological conditions. Thousands of operations, performed all over the world, clearly confirm this statement (Wardana, R, 2019). However, this paper will demonstrate that there are geological features where the main advantage of RSS – drilling with constant rotation – is not efficient and may result in emergency situations. Specifically, under such geological conditions it is necessary to drill in Tazovskoye field which is developed by extended reach horizontal and multilateral wells. This paper will cover integrated engineering solutions, which made it possible to overcome geological challenges to reduce the costs of drilling extended reach multilateral wells by a deliberate engineered change from RSS to PDM application. The approach was confirmed in 11 multilateral wells, drilled with the use of PDM. In this case the length of each horizontal hole totaled 2000 meters and more. An all-time record was achieved in Russia in terms of the length of horizontal wells, drilled with PDM motors without using oil-based mud: a horizontal section 2,520 meters in length with DDI – 6.72, ERD – 2.67 was drilled.

OnePetro

doi: 10.2523/IPTC-23061-MS

IPTC

IPTC-23061-MS

International Petroleum Technology Conference

Country: Asia > Russia > Ural Federal District > Yamalo-Nenets Autonomous Okrug > Purovsky District (0.91)

Industry: Energy > Oil & Gas > Upstream (1.00)

Oilfield Places:

Asia > Russia > Ural Federal District > Yamalo-Nenets Autonomous Okrug > Purovsky District > West Siberian Basin > Central Basin > Tazovskoye Field (0.99)
Asia > Russia > Far Eastern Federal District > Sakha Republic (Yakutia) > East Siberian Basin > Nepa-Botuoba Basin > Chayandinskoye Field (0.99)

SPE Disciplines: Well Drilling > Drilling Operations > Directional drilling (1.00)

Technology: Information Technology > Information Management (0.34)

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Novatek Discovers New Arctic Gas Field as Russian LNG Exports to Europe Soar

Journal of Petroleum TechnologyJanuary, 2023

Russia's largest independent gas producer, Novatek, has discovered a new gas condensate field after having tested its first exploration well within the Bukharinskiy license area adjacent to the company's Trekhbugorniy license area in the Gydan Peninsula, expanding the company's resource base as record imports of Russian LNG flowed to Europe in 2022. Novatek's Arctic LNG 1 subsidiary discovered the new field with estimated recoverable reserves of 52 Bcm of natural gas and 2 million tons of liquids under the Russian reserve reporting standards, as confirmed by the State Reserves Commission, Novatek reported. Named "Girya" after geologist Novatek co-founder Viktor Girya, the discovery boosts the resource base for the company's Arctic LNG 1 project, which is in the exploration stage and, if pursued, would unlikely be realized before 2030. Arctic LNG 1 would be Novatek's fourth LNG facility, if built. Meanwhile, Novatek had planned to launch the first of the three trains planned for its 19.8 mtpa Arctic LNG 2 project in 2023 (its second LNG plant). This year the company also planned to make a final investment decision on the 5 mtpa Obsky LNG facility, a third plant to be built using Russian technologies and domestically manufactured equipment.

Journal of Petroleum Technology

arctic lng 1, arctic lng 2, asia government, discover new arctic gas field, europe government, europe soar, France, gas monetization, importer, liquefied natural gas, liquified natural gas, LNG, Midstream Oil & Gas, Novatek, russia government, russian government, russian lng export, totalenergies, yamal lng

Country:

Europe (1.00)
Asia > Russia > Ural Federal District > Yamalo-Nenets Autonomous Okrug (0.38)
Asia > Russia > Ural Federal District > Tyumen Oblast > Yamalo-Nenets Autonomous Okrug (0.25)

Industry: Energy > Oil & Gas > Midstream (1.00)

Oilfield Places:

Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > North Kuwait Jurassic (NKJ) Fields > Marrat Formation > Upper Marrat Formation (0.94)
Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > North Kuwait Jurassic (NKJ) Fields > Marrat Formation > Sargelu Formation (0.94)

SPE Disciplines: Facilities Design, Construction and Operation > Natural Gas Conversion and Storage > Liquified natural gas (LNG) (1.00)

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Russia Is Staring at $60/bbl Oil Now and Plenty More Problems Ahead

Journal of Petroleum TechnologyDecember, 2022

When oil price controls took effect last weekend, Russia said it would not sell oil to countries insisting on contracts that impose a $60/bbl cap on the oil price. It is the latest in a series of defiant responses to Western sanctions designed to reduce its oil export revenues. But in this case, the cap is only a few dollars below the benchmark price used when pricing exports--the Urals blend. Since Russia benefitted from an initial surge in oil prices after it invaded Ukraine this spring, which lasted into early summer, oil prices have declined. The current value of a barrel of Brent is just below $80, which is pretty good compared to where it has been most of the time since 2014.

Journal of Petroleum Technology

Country:

Europe > Russia (1.00)
Asia > Russia > Ural Federal District > Yamalo-Nenets Autonomous Okrug (0.15)

Industry: Energy > Oil & Gas > Upstream (1.00)

Oilfield Places: Asia > Russia > Ural Federal District > Yamalo-Nenets Autonomous Okrug > West Siberian Basin > Central Basin > Kharampurskoye Field (0.99)

SPE Disciplines:

Management (1.00)
Facilities Design, Construction and Operation > Natural Gas Conversion and Storage > Liquified natural gas (LNG) (1.00)

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Features of the organization, control and modeling underground storage facilities at the oil and gas Cenomanian formation (Russian)

Osipenko, A. S. (Gazpromneft STC LLC) | Samorokov, S. V. (Gazpromneft STC LLC) | Meledin, A. S. (Ufa Scientific and Technical Center LLC) | Loginova, D. S. (University of Tyumen) | Tengelidi, D. I. (Messoyakhaneftegas JSC)

OnePetroDecember, 2022

The organization of an underground gas storage facility (UGS) at the Zapadno-Messoyakhsky area of the Vostochno-Messoyakhskoye field has been proposed in order to minimize economic costs and to significantly reduce environmentally harmful emissions into the atmosphere during the utilization of associated petroleum gas (APG). A feature of this UGS facility is the gas injection into a productive formation containing an oil rim and a gas cap. In this regard, it is necessary to prevent the dilution of oil reserves during the exploitation of the gas storage and ensure the inclusion of oil reserves in the development. As part of the project implementation, a cluster of injection gas wells was built, and control of changes in the gas cap of the PK1-3 formation associated with APG injection was organized. The article considers the evaluation of a number of projected risks of the facility: dropout of hydrates in the reservoir, hydrate formation in the wells of the active fund, as well as clarification of the hydrodynamic connection of the facility blocks and the possible volume of gas injection before its breakthrough under the water-oil contact. The main tool is hydrodynamic reservoir model, which allow take into account the specifics of the geological structure, the history of the exploitation of the facility, and the decisions made to organize and control the underground storage facilities at the Zapadno-Messoyakhsky area. Recommendations were made on well operation modes to minimize risk of hydrate dropout. A tool was created to evaluate the dynamics of hydrate formation risks based on well operation data, measurements in control well and the results of hydrodynamic modeling. The volume of gas injection before breakthroughs into the oil rim and under the oil rim has been estimated. A number of recommendations were issued for the exploitation of underground storage facilities. The obtained results, tools and approaches to modeling can be used in the future to control the exploitation of underground storage facilities at Zapadno-Messoyakhsky area, as well as be applied to analogue facilities.

OnePetro

doi: 10.24887/0028-2448-2022-12-70-74

OIJ

OIJ-2022-12-070-074-RU

Oil Industry Journal

Country: Asia > Russia > Ural Federal District > Yamalo-Nenets Autonomous Okrug > Tazovksy District (0.54)

Industry: Energy > Oil & Gas > Upstream (1.00)

SPE Disciplines:

Reservoir Description and Dynamics > Storage Reservoir Engineering > Natural gas storage (1.00)
Reservoir Description and Dynamics > Improved and Enhanced Recovery > Gas-injection methods (0.95)

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The use of enzymes as a new method for production intensification (Russian)

Takhirov, A. A. (Gazpromneft STC LLC) | Onuchin, S. V. (Gazpromneft STC LLC) | Mikhlik, A. G. (Messoyakhaneftegas JSC) | Minnebaev, B. R. (Messoyakhaneftegas JSC) | Oleynik, A. A. (Messoyakhaneftegas JSC)

OnePetroDecember, 2022

The article discusses the theoretical foundations, world experience, as well as the key results of laboratory studies of the enzyme composition used to stimulate oil production and as a enhanced oil recovery method. Currently, there are some of the problems at fields with low temperature, high oil viscosity and high reservoir properties such as the impossibility to create a high drawdown on the reservoir (in conditions of shallow reservoirs), the migration of reservoir particles and, as a result, clogging of the liner filter, which in turn causes decrease in production rate for many wells, especially for sand-bearing wells working for objects with high-viscosity oil. The formation of a filter cake on the filter part of the liner consisting of a mixture of high-viscosity oil and sandstone particles, as well as the low phase permeability for oil of a hydrophobic reservoir, can partially or completely block the flow of fluid into the well and act as a local skin factor in the bottomhole formation zone. The solution to this problem can be methods that reduce the viscosity of oil: thermal and chemical, one of which is the use of an enzyme composition to destroy high-molecular compounds of hydrocarbons and to change the wettability of the reservoir to hydrophilic. To confirm these effects, laboratory filtration studies were carried out on core from the Vostochno-Messoyakhskoye field. Two groups of tests were carried out with enzyme concentrations of 2.5 and 10%, respectively, as a result, an increase in displacement ratio from 2.4 to 6.9% (depending on the concentration of the solution) was obtained and the recovery of phase permeability after enzyme filtration was 15% greater, than after water filtration.

OnePetro

doi: 10.24887/0028-2448-2022-12-56-59

OIJ

OIJ-2022-12-056-059-RU

Oil Industry Journal

Country: Asia > Russia > Ural Federal District > Yamalo-Nenets Autonomous Okrug > Tazovksy District (0.54)

Genre: Overview > Innovation (0.40)

Industry: Energy > Oil & Gas > Upstream (1.00)

Oilfield Places: Asia > Myanmar > Magway Region > Myanmar Central Basin > Salin Basin > Mann Field (0.99)

SPE Disciplines:

Reservoir Description and Dynamics > Improved and Enhanced Recovery (1.00)
Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (0.56)

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Laboratory Studies for Design of a Foam Pilot for Reducing Gas Channeling from Gas Cap in Production Well in Messoyakhskoye Field

Saifullin, Emil (Kazan Federal University (Corresponding author)) | Zhanbossynova, Shinar (Kazan Federal University) | Zharkov, Dmitrii (Kazan Federal University) | Yuan, Chengdong (Kazan Federal University (Corresponding author)) | Varfolomeev, Mikhail (Kazan Federal University (Corresponding author)) | Zvada, Maiia (Gazpromneft STC)

OnePetroAugust, 2022

Summary This paper highlights the difference between foam injection for gas blocking in production well and injection well and emphasizes the use of polymer enhanced foam. Moreover, this paper shows systematic experimental methods for choosing suitable foam systems for gas blocking in production well considering different factors, which provides a guide regarding what kinds of foaming agents and polymer stabilizers should be used and how to evaluate them for designing a pilot application. The target in this work is the Vostochno-Messoyakhskoye field, operated by Gazpromneft, which is currently experiencing gas channeling from the gas cap in production wells because of strong heterogeneity. Foam has long been considered as a good candidate for gas blocking. However, foam injection for gas blocking in production wells is different from that in injection wells, which requires a long-term impact on gas-saturated highly permeable areas without significantly affecting the phase permeability of oil in the reservoir. Therefore, for gas blocking in production well, a long half-life time of foam is required to sustain stable foam because a continuous shear of surfactant solution/gas cannot be achieved as in injection wells. Thus, reinforced foam by polymer (polymer-foam) is chosen. Four polyacrylamide polymer stabilizers and five anionic surfactants were evaluated using bulk test to determine foaming ability, foam stability, and effect of oil by comparing foam rate and half-life time to determine the suitable foam system with optimal concentrations of reagents. Furthermore, filtration experiments were conducted at reservoir conditions to determine the optimal injection mode by evaluating apparent viscosity, breakthrough pressure gradient, resistance factor, and residual resistance factor. Polymer can significantly improve half-life time (increase foam stability), and the higher the polymer concentration, the longer the half-life time. But simultaneously, a high polymer concentration will increase the initial viscosity of the solution, which not only decreases the foam rate but also increases difficulties in injection. Therefore, an optimal polymer concentration of about 0.15–0.2 wt% is determined considering all these influences. Filtration experiments showed that the apparent viscosity in the core first increased and then decreased with foam quality (the volumetric ratio of gas to total liquid/gas flow). The optimal injection mode is coinjection of surfactant/polymer solution and gas to in-situ generate foam at the optimal foam quality of about 0.65. Filtration experiments on the different permeability cores showed that the gas-blocking ability of polymer-foam is better in high-permeability cores, which is beneficial for blocking high-permeability zone. It should also be noted that under a certain ratio of oil-to-foam solution (about lower than 1 to 1), the presence of high-viscosity crude oil slowly decreased the foam rate with increasing oil volume, but significantly increased the half-life time (i.e., foam stability which is favorable for foam treatment in production well).

OnePetro

doi: 10.2118/206435-PA

SPE

SPE-206435-PA

SPE Reservoir Evaluation & Engineering

Country: Asia > Russia > Ural Federal District > Yamalo-Nenets Autonomous Okrug > Tazovksy District (1.00)

Genre: Research Report > New Finding (0.34)

Industry: Energy > Oil & Gas > Upstream (1.00)

Oilfield Places:

Europe > Norway > North Sea > Northern North Sea > North Viking Graben > PL 104 > Block 30/9 > Oseberg Field > Tarbert Formation (0.99)
Europe > Norway > North Sea > Northern North Sea > North Viking Graben > PL 104 > Block 30/9 > Oseberg Field > Oseberg Formation (0.99)
Europe > Norway > North Sea > Northern North Sea > North Viking Graben > PL 079 > Block 30/9 > Oseberg Field > Tarbert Formation (0.99)
(16 more...)

SPE Disciplines:

Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
Reservoir Description and Dynamics > Improved and Enhanced Recovery > Chemical flooding methods (1.00)

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Novatek Plans To Use Drones To Find Methane Leaks

Journal of Petroleum TechnologyAugust, 2022

Novatek announced that one of its subsidiaries, Novatek-Yurkharovneftegas, has launched a project for methane leak monitoring with the use of unmanned aerial vehicles (UAVs). Using UAVs for methane leak monitoring enables accurate and fast measurements as well as lower costs compared with other monitoring methods. The project involves using domestically sourced UAVs to inspect the facilities of the Yurkharovskoye field, one of the largest in the company's portfolio, and the West-Yaroyakhinskiy license area, spanning almost 100 hectares, as well as a 50-km long section of Novatek's gas pipelines. Designed with hypersensitive gas analyzers, UAVs are equipped to operate in remote areas and deliver real-time video feeds within up to 50 km. The company called the UAVs an important element of the multilevel methane leak detection system, which includes satellite imaging and ground monitoring during site tours.

Journal of Petroleum Technology

air emission, Artificial Intelligence, climate change, methane intensity, methane leak, novatek plan, UAV, use drone

Country: Asia > Russia > Ural Federal District > Yamalo-Nenets Autonomous Okrug > Gulf of Ob (0.28)

SPE Disciplines:

Health, Safety, Environment & Sustainability > Environment > Climate change (1.00)
Health, Safety, Environment & Sustainability > Environment > Air emissions (1.00)

Technology: Information Technology > Artificial Intelligence > Robots > Autonomous Vehicles > Drones (0.74)

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Novatek JV Wins North Yarudeyskoye License

Journal of Petroleum TechnologyAugust, 2022

Novatek's Yargeo joint venture has won the license to survey, explore, and develop production at the North Yarudeyskoye oil and gas condensate field over the next 27 years. The license area is in the Yamal-Nenets autonomous region in the Arctic, Russia's principal gas-producing area. North Yarudeyskoye holds an estimated hydrocarbon resource potential of 93.5 million BOE. The greater Yarudeyskoye field began producing in 2015 and by 2017 was responsible for nearly a third of Novatek's liquids production. The company, Russia's largest private natural gas producer, noted that it had participated in the recent auction to explore and develop North Yarudeyskoye through Gazprom Bank's Electronic Trading Platform and that the win was Novatek's first on that platform.

Journal of Petroleum Technology

complex reservoir, condensate reservoir, jv win north yarudeyskoye license, Novatek, Russia, Upstream Oil & Gas

Country: Asia > Russia > Ural Federal District > Yamalo-Nenets Autonomous Okrug (0.69)

Industry: Energy > Oil & Gas > Upstream (1.00)

Oilfield Places: Asia > Russia > Ural Federal District > Yamalo-Nenets Autonomous Okrug > West Siberian Basin > Yarudeyskoye Field (0.99)

SPE Disciplines:

Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Gas-condensate reservoirs (1.00)
Production and Well Operations (0.69)
Management (0.69)

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E&P Notes (August 2022)

JPT staff, _ (SPE)

OnePetroAugust, 2022

Valaris Adds Fresh Rig Contracts to Backlog Valaris has scooped a number of new contracts and contract extensions, adding an associated $466 million to its contract backlog. The company received a 540-day contract with Equinor offshore Brazil for use of drillship Valaris DS-17. The rig will be reactivated for this contract, which is expected to begin in mid-2023. The total contract value is around $327 million, including an upfront payment totaling $86 million for mobilization costs, a contribution toward reactivation costs, and capital upgrades. The remaining contract value relates to the operating day rate and additional services. Also in Brazil, Valaris received a contract extension with TotalEnergies EP Brasil offshore Brazil for the use of drillship Valaris DS-15. The option is in direct continuation of the current firm program. “We are particularly pleased to have been awarded another contract for one of our preservation stacked drillships, Valaris DS-17, and look forward to partnering with Equinor on their flagship Bacalhau project in Brazil,” said Valaris Chief Executive Anton Dibowitz. “We expect Brazil to be a significant growth market for high-specification floaters over the next several years, and we are well positioned to benefit by now adding a third rig to this strategic basin.” The contractor also was awarded a two-well contract extension with Woodside offshore Australia for semisubmersible Valaris DPS-1. The two-well extension has an estimated duration of 38 days and will be in direct continuation of the existing firm program for Woodside’s Enfield plug-and-abandonment (P&A) campaign. The P&A work covers 18 wells in total. Woodside also awarded Valaris a separate one-well extension for the rig. The work has an estimated duration of 60 days with Woodside’s Scarborough development campaign. Elsewhere, Shell awarded a 4-year contract for heavy-duty modern jackup Valaris 115 offshore Brunei. The $159-million contract is expected to begin in April 2023. The contract was also awarded various short-term deals for jackups with Shell in the UK, an undisclosed operator in the Gulf of Mexico (GOM), Cantium in the GOM, and GB Energy offshore Australia. Shell Joins Equinor in GOM Sparta Development Shell has agreed to purchase 51% of Equinor’s interest in the North Platte deepwater development project in the US Gulf of Mexico (GOM). Equinor will retain 49% interest in the project, and Shell will become the new operator of the field. The new partners also have agreed to rename North Platte to Sparta. Sparta straddles four blocks of the Garden Banks area, 275 km off the coast of Louisiana in approximately 1300 m of water depth. Front-end engineering and design has been matured for the project. Equinor and Shell will review the work that has been completed and update the development plan. Shell said that Sparta aligns with its strategy to pursue upstream investments that can remain competitive over time, both from a financial and environmental-intensity perspective. North Platte was discovered by Cobalt Energy and Total in 2012. The partners said the Wilcox-aged discovery would require 20K-psi technology to develop. Cobalt went bankrupt in 2017 and its stake in the asset was sold to Equinor and Total. In early 2022, TotalEnergies walked away from the project and its operatorship to focus on other projects, leaving Equinor with 100% interest. BP Awarded King Mariout Block in Egypt’s West Med BP has been awarded the King Mariout exploration block offshore Egypt following its participation last year in the limited bid round organized by the Egyptian Natural Gas Holding Company. The King Mariout Offshore area is located 20 km west of the Raven field in the Mediterranean Sea and covers 2600 km with water depths ranging between 500 and 2100 m. The block is within the West Nile Delta area, for which material gas discoveries could be developed using existing infrastructure. BP holds a 100% stake in the block. BP is a major player in Egypt investing more than $35 billion in the area over the past 60 years. LLOG Begins Production From Spruance in GOM LLOG has kicked off production from its operated Spruance Field located in Ewing Bank Blocks 877 and 921 in the US GOM. The two-well subsea development is producing, in combination, approximately 16,000 B/D of oil and 13 MMcf/D via a 14-mile subsea tieback to the EnVen-operated Lobster platform in nearby Block 873. The Spruance Field was initially discovered by LLOG and its partners in mid-2019 via a subsalt exploratory well, the Ewing Bank 877 #1, which was drilled in 1,570 ft to a total depth of 17,000 ft and logged around 150 net ft of oil pay in multiple high-quality Miocene sands. A second well, the Ewing Bank 921 #1, was drilled from the same surface location as the discovery well to a total depth of 16,600 ft in early October 2020. The well delineated the main field pays and logged additional oil pay in the exploratory portion of the well, finding a total of more than 200 net ft of oil. LLOG is the operator of the Spruance Field and owns a 22.64% working interest with partners Ridgewood Energy (23.89%), EnVen (13.5%), Beacon Asset Holdings (11.61%), Houston Energy (11.2%), Red Willow (11.15%), and CL&F (6%). Egypt Signs Agreement With Chevron To Drill First Exploration Well in East Med Chevron is planning to drill the first exploration well in its concession area in the Eastern Mediterranean this September. The well plans come as Egyptian Natural Gas Holding signed a memorandum of understanding with the US-based producer to cooperate in transporting, importing, and exporting natural gas from the area. Chevron expanded its presence in the area following its $5-billion acquisition of Noble Energy in 2020. The two companies will evaluate options for natural gas transmission from the East Mediterranean to Egypt to optimize its value through liquefaction before re-exporting and selling it, according to the memorandum. In addition, the two firms will perform research on low-carbon natural gas. APA Suriname Campaign Offers Mixed Results APA Corporation successfully flow tested its Krabdagu exploration well (KBD-1) on Block 58 offshore Suriname, while its Rasper exploration well on Block 53 offered disappointing results. Flow-test data collected in the two lower intervals, the Upper Campanian (32 m of net oil pay) and Lower Campanian (32 m of net oil pay), indicate oil-in-place resources of approximately 100 million bbl and 80 million bbl, respectively, connected to the KBD-1 well. Appraisal drilling will be necessary to confirm additional resource and development-well locations, according to APA. The exploration well encountered another high-quality interval in the Upper Campanian that was not in a location suitable for flow testing. This shallower Campanian zone will need to be flow tested in the appraisal stage from a better location. The APA-TotalEnergies joint venture is currently drilling the Dikkop exploration well in the central portion of Block 58 with drilling rig Maersk Valiant. Following completion of operations at Dikkop, the rig is expected to continue exploration and appraisal activities in the central portion of Block 58. APA Suriname and operator TotalEnergies each hold a 50% working interest in the block. Meanwhile, APA’s Rasper well in Block 53 off Suriname encountered water-bearing reservoirs in the Campanian and Santonian intervals. The Noble Gerry de Souza drillship has been mobilized to the next exploration prospect, Baja, in the southwestern corner of Block 53. Baja lies 11 km northeast of the recently announced Block 58 discovery at Krabdagu and will test Maastrichtian and Campanian targets. APA Suriname, the operator, holds a 45% working interest in the block, Petronas holds a 30% working interest, and CEPSA a 25% working interest. Novatek JV Wins North Yarudeyskoye License Novatek’s Yargeo joint venture has won the license to survey, explore, and develop production at the North Yarudeyskoye oil and gas condensate field over the next 27 years. The license area is in the Yamal-Nenets autonomous region in the Arctic, Russia’s principal gas-producing area. North Yarudeyskoye holds an estimated hydrocarbon resource potential of 93.5 million BOE. The greater Yarudeyskoye field began producing in 2015 and by 2017 was responsible for nearly a third of Novatek’s liquids production. The company, Russia’s largest private natural gas producer, noted that it had participated in the recent auction to explore and develop North Yarudeyskoye through Gazprom Bank’s Electronic Trading Platform and that the win was Novatek’s first on that platform. PDC Energy Gets Green Light for Kenosha, Broe Developments The Colorado Oil and Gas Conservation Commission has approved PDC Energy’s Kenosha and Broe developments’ permit applications. The Kenosha development, which encompasses 69 wells on three pads in rural Weld County, Colorado, further increases PDC’s permitted inventory by another rig year and solidifies drilling and completion activity well into 2024. The Broe permit encompasses 30 wells in rural Weld County. The Broe plan was initiated by Great Western Petroleum, which was acquired by PDC in May 2022 and represents PDC’s first development plan approval on Great Western acreage. Combined with the Kenosha plan approval, PDC added 99 new wells to its inventory in June and will soon have more than 675 permits and drilled and uncompleted wells. Both fields are in the greater Wattenberg area. The new permits add to an already-established multiyear inventory of projects in the DJ Basin. Kenosha is the second oil and gas development plan to be approved, and the company anticipates further approvals with its Guanella area plan and others. PDC’s operations in the Wattenberg field are focused in the horizontal Niobrara and Codell plays. The Wattenberg represents PDC Energy’s largest asset with more than 85% of its 2021 production and 90% of its year-end 2021 proved reserves.

OnePetro

doi: 10.2118/0822-0012-JPT

SPE

SPE-0822-0012-JPT

Journal of Petroleum Technology