Rapid Pressure Support for Champion SE Reservoirs by Multi-Layer Fractured Water Injection

2006 ◽  
Author(s):  
Gerald Sommerauer ◽  
Christoph Zerbst
Keyword(s):  
Pressure Support ◽  
Water Injection ◽  
Rapid Pressure

Rapid Pressure Support for Champion SE Reservoirs by Multilayer Fractured Water Injection

2007 ◽  
Vol 22 (04) ◽  
pp. 356-368 ◽  
Author(s):  
Gerald Sommerauer ◽  
Christoph Zerbst
Keyword(s):  
Pressure Support ◽  
Water Injection ◽  
Rapid Pressure

Optimizing Field Development in South Sultanate of Oman Through Deep Water Disposal Dwd Reclassification

2021 ◽  
Author(s):  
Ali Al Jumah ◽  
Abdulkareem Hindawi ◽  
Fakhriya Shuaibi ◽  
Jasbindra Singh ◽  
Mohamed Siyabi ◽  
...  
Keyword(s):  
Deep Water ◽  
Pressure Support ◽  
Local Community ◽  
Water Injection ◽  
Flood Management ◽  
Water Volume ◽  
Reed Beds ◽  
Field Development ◽  
Palm Trees ◽  
Water Disposal

Abstract The South Oman clusters A and B have reclassified their Deep-Water Disposal wells (DWD) into water injection (WI) wells. This is a novel concept where the excess treated water will be used in the plantation of additional reed beds (Cluster A) and the farming of palm trees (Cluster B), as well as act as pressure support for nearby fields. This will help solve multiple issues at different levels namely helping the business achieve its objective of sustained oil production, helping local communities with employment and helping the organization care for the environment by reducing carbon footprints. This reclassification covers a huge water volume in Field-A and Field-B where 60,000 m3/day and 40,000 m3/day will be injected respectively in the aquifer. The remaining total excess volume of approx. 200,000m3/d will be used for reed beds and Million Date Palm trees Project. The approach followed for the reclassification and routing of water will: Safeguard the field value (oil reserves) by optimum water injectionMaintain the cap-rock integrity by reduced water injection into the aquifer.Reduce GHG intensity by ±50% as a result of (i) reduced power consumption to run the DWD pumps and (ii) the plantation of trees (reed beds and palm trees).Generate ICV (in-country value) opportunities in the area of operations for the local community to use the excess water at surface for various projects.Figure 1DWD Reclassification benefits Multiple teams (subsurface. Surface, operations), interfaces and systems have been associated to reflect the re-classification project. This was done through collaboration of different teams and sections (i.e. EC, EDM, SAP, Nibras, OFM, etc). Water injection targets and several KPIs have been incorporated in various dashboards for monitoring and compliance purposes. Figure 2Teams Integration and interfaces It offers not only a significant boost to the sustainability of the business, but also pursues PDO's Water Management Strategy to reduce Disposal to Zero by no later than the year 2030 This paper will discuss how the project was managed, explain the evaluation done to understand the extent of the pressure support in nearby fields from DWD and the required disposal rate to maintain the desired pressures. Hence, reclassifying that part of deep-water disposal volume to water injection (WI) which requires a totally different water flood management system to be built around it.

The Forties Field, Block 21/10, 22/6a, UK North Sea

1991 ◽  
Vol 14 (1) ◽  
pp. 301-308 ◽  
Author(s):  
J. M. Wills
Keyword(s):  
North Sea ◽  
Pressure Support ◽  
Significant Contribution ◽  
Average Rate ◽  
Water Injection ◽  
Submarine Fan ◽  
Artificial Lift ◽  
Stock Tank ◽  
Year 2000 ◽  
Exploration Well

AbstractThe Forties Field is located 180 km (112 miles) ENE of Aberdeen, predominantly in UK Licence Block 21/10. It was discovered in 1970, when an exploration well encountered hydrocarbons in Palaeocene sandstone within an anticlinal structure. Four appraisal wells confirmed the existence of a major oilfield, with an area of approximately 90 sq km (35 sq miles) at a depth of approximately 2000 m (6500 ft). The reservoir occurs in thick Late Palaeocene sandstones deposited in two major sand-rich submarine fan sequences.The field has been producing oil since September 1975. Stock Tank Oil Initially in Place (STOIIP) has been calculated as 4343 MMBBL, and original reserves estimated as 2470 MMBBL, representing an overall recovery of 57%. The field came off plateau production of 500 000 BOPD in 1981, and by mid-1989 production had declined to about 250 000 BOPD. After fourteen years production, the field has produced more than 2 billion STB. Remaining reserves are about 500 MMBBL which includes recovery via artificial lift. Field life has been projected to extend beyond the year 2000.Water injection into the aquifer commenced in 1976, and continues at the present day at an average rate of 390 000 BWPD. There is also a significant contribution to pressure support from the underlying aquifer.At present there are 103 available wells in the field, 81 producers and 22 injectors.

The Pierce Field, Blocks 23/22a and 23/27, UK North Sea

2020 ◽  
Vol 52 (1) ◽  
pp. 550-559 ◽  
Author(s):  
M. Hale ◽  
R. Laird ◽  
J. Gavnholt ◽  
P. F. van Bergen
Keyword(s):  
Pressure Support ◽  
Water Injection ◽  
East Central ◽  
Field Development ◽  
Gas Compression ◽  
Phases Of Development ◽  
Original Field ◽  
Reservoir Geometry ◽  
The Uk ◽  
Ratio Optimization

AbstractThe Pierce Field lies 250 km east of Aberdeen, in the UK sector of the East Central Graben. The field comprises twin salt diapirs, forming the trap for oil and free gas in the Paleocene–Eocene Forties Sandstone Member reservoir. The diapirs exerted a strong influence over the sedimentation of the reservoir, with the construction of multistorey sandstone bodies forming a complex reservoir geometry further complicated by a hydrodynamic aquifer.The field currently produces to the Haewene Brim floating production storage and offloading (FPSO) installation, and has undergone several phases of development as the understanding has matured. It was initially developed with six subsea horizontal oil producers tied back to the FPSO, with produced gas reinjected through two gas injectors. In 2004–05, water injection was introduced to South Pierce to provide increased pressure support and improve sweep. To maximize recovery, four additional oil producers were drilled between 2010 and 2016, with the final (third) gas injector drilled in 2010. Production is primarily constrained by topsides gas compression capacity leading to gas/oil ratio optimization being the focus of the current field management strategy.The final phase of field development, included in the original field development plan, involves depressurization of the field with the installation of a gas export line.

Pressure Support Through Large Scale Gas Cap Water Injection At Prudhoe Bay

2002 ◽  
Author(s):  
Jhaveri Bharat ◽  
Gary Youngren ◽  
Joe Dozzo ◽  
Lynn Schnell ◽  
Matt Maguire
Keyword(s):  
Large Scale ◽  
Pressure Support ◽  
Water Injection ◽  
Prudhoe Bay

scholarly journals Insights into the recurrent energetic eruptions on Awu, one of the deadliest volcano on earth

2020 ◽  
Author(s):  
Philipson Bani ◽  
Syegi Kunrat ◽  
Devy Kamil Syahbana ◽  
Keyword(s):  
Crater Lake ◽  
Lava Dome ◽  
Water Injection ◽  
Annual Rainfall ◽  
Water Evaporation ◽  
Crater Wall ◽  
Gas Emission ◽  
The Past ◽  
Future Events ◽  
Rapid Pressure

Abstract. The little know Awu volcano is among the deadliest with a cumulative dead toll of 11048. In less than 4 centuries, 18 eruptions were recorded, including two VEI-4 and three VEI-3 with worldwide impacts. The regional geodynamic is controlled by a divergent-double-subduction and an arc-arc collision. In that context, the slab stalls in the mantle, undergoes an increase of temperature and becomes prone to melting, a process that sustained the magmatic supply. Awu also has the particularity to host alternatively and simultaneously a lava dome and a crater lake throughout its activity. The lava dome occurred passively through the crater lake and induced strong water evaporation from the crater. A conduit plug associated with this dome emplacement subsequently channeled the gas emission to the crater wall. However, with the lava dome cooling, the high annual rainfall eventually reconstituted the crater lake and creating a hazardous situation on Awu. Indeed with a new magma injection, rapid pressure buildup may pulverize the conduit plug and the lava dome, allowing lake water injection and subsequent explosive water-magma interaction. The past vigorous eruptions are likely induced by these phenomena, a possible scenario for the future events.

The Harding Field, Block 9/23b

2003 ◽  
Vol 20 (1) ◽  
pp. 283-290 ◽  
Author(s):  
J. Beckly ◽  
T. Nash ◽  
R. Pollard ◽  
C. Bruce ◽  
P. Freeman ◽  
...  
Keyword(s):  
Mass Flow ◽  
Heavy Oil ◽  
Pressure Support ◽  
Water Injection ◽  
Reservoir Quality ◽  
Western Flank ◽  
Flow Processes ◽  
Extended Reach Drilling ◽  
Structural Closure ◽  
Psi Production

AbstractThe Harding Field was discovered in 1988 and lies within Block 9/23b, 320 km NE of Aberdeen, on the western flank of the Crawford Ridge. Appraisal drilling found a series of Tertiary accumulations along the Crawford Ridge, and, though most have an apparent element of stratigraphic trapping, a larger structural closure is possible. The present development comprises two heavy oil accumulations, Central and South, reservoired in massive sands of the Eocene Balder Formation. Deposited by mass flow processes, these clean and well-sorted sands have been further homogenized by post depositional remobilization and injection. There are seven horizontal producers in Central and three in South, with pressure support by water injection. Reservoir quality is exceptional, with permeability in excess of ten darcies and Pi's for the horizontal producers in excess of 1000 STB/psi. Production started in April 1996 achieving a plateau rate in excess of 90 MMSTBPD with 40% of the estimated 200 MMSTB reserves recovered in the first three years.Four smaller Tertiary satellite pools are presently under appraisal and development by extended reach drilling from the platform.

scholarly journals Insights into the recurrent energetic eruptions that drive Awu, among the deadliest volcanoes on Earth

2020 ◽  
Vol 20 (8) ◽  
pp. 2119-2132 ◽  
Author(s):  
Philipson Bani ◽  
Syegi Kunrat ◽  
Devy Kamil Syahbana ◽  
Keyword(s):  
Crater Lake ◽  
Lava Dome ◽  
Water Injection ◽  
Annual Rainfall ◽  
Water Evaporation ◽  
Geodynamic Setting ◽  
Gas Emission ◽  
The Past ◽  
Future Events ◽  
Rapid Pressure

Abstract. The little-known Awu volcano (Sangihe Islands, Indonesia) is among the deadliest, with a cumulative death toll of 11 048. In less than 4 centuries, 18 eruptions were recorded, including two VEI 4 and three VEI 3 eruptions with worldwide impacts. The regional geodynamic setting is controlled by a divergent-double-subduction collision and an arc–arc collision. In that context, the slab stalls in the mantle, undergoes an increase in temperature, and becomes prone to melting, a process that sustained the magmatic supply. Awu also has the particularity of hosting alternatively and simultaneously a lava dome and a crater lake throughout its activity. The lava dome passively erupted through the crater lake and induced strong water evaporation from the crater. A conduit plug associated with this dome emplacement subsequently channeled the gas emission to the crater wall. However, with the lava dome cooling, the high annual rainfall eventually reconstituted the crater lake and created a hazardous situation on Awu. Indeed with a new magma injection, rapid pressure buildup may pulverize the conduit plug and the lava dome, allowing lake water injection and subsequent explosive water–magma interaction. The past vigorous eruptions are likely induced by these phenomena, possible scenarios for future events.

Ingenious Method for Water Injection Optimization on Mature Carbonate Reservoir with Rapid Pressure Decline Problem, Case Study: XJN Field - South Sumatra, Indonesia

2021 ◽  
Author(s):  
M. Arief Salman Alfarizi ◽  
Marja Dinata ◽  
Rizki Ananda Parulian ◽  
Kamal Hamzah ◽  
Tejo Sukotrihadiyono ◽  
...  
Keyword(s):  
History Matching ◽  
Water Injection ◽  
Material Balance ◽  
Injection Rate ◽  
Carbonate Reservoir ◽  
Integrated Analysis ◽  
Close Monitoring ◽  
Reservoir Pressure ◽  
Production Loss ◽  
Rapid Pressure

Abstract XJN field has implemented water injection as pressure maintenance since 1987, only one year after initial production. XJN is carbonate reservoir with weak aquifer underlying the oil zone. Initial reservoir pressure was 2,700 psi and peak production was 27,000 BOPD. Reservoir pressure was drop to 1,800 psi within 5 years of production. During 1991-2007, better injection management was performed to provide negative voidage. This action has managed to bring reservoir pressure back to its initial pressure, eventually enabling all wells to be converted from gaslift to naturalflow. In 2013, watercut has increased to 97% and several naturally flowing wells began to ceased-to-flow, then production mode was changed gradually from naturalflow to artificial lift using Electric Submersible Pump (ESP). In 2017-2020, there was rapid reservoir pressure decline around 300 psi/year while XJN water injection performance considered flawless. Voidage Replacement Ratio (VRR) was 1.3, but reservoir pressure was kept declining. This situation will cause ESP pump off on producer wells which in turn means big production loss. This paper will elaborate about the simple-uncommon-yet effective methods for problem detection and its solution to revive pressure and production. Analysis was began with observing the deviation of VRR and reservoir pressure, this was to estimate "leak" time of water injection. Next analysis was evaluation of injection rate leak off using material balance with reverse history matching. Reverse here means making reservoir pressure as main constraint rather than history matching goal. After that, it was continued with water injection flow path analysis. This was done by plotting production-injection-pressure data then make several small groups of injector-producer based on visible relationships. The purposes were to find key injector wells and to shut-in all inefficient ones. Furthermore, injection re-distribution was also performed based on VRR calculation on groups from previous step, water distribution priority was focused on key injector wells. These analysis have also paved the way for searching channeling possibility on injector wells. The results, XJN reservoir pressure showed an increasing trend of 100 psi/year after optimization was performed, with current pressure around 2000 psi. The increase in reservoir pressure has also made it possible to optimize ESP, field lifting has increased for 5000 BLPD. This project has also successfully secured XJN remaining oil. This project was racing with rapid pressure decline that will lead to early ESP pump off and production loss. The integrated subsurface analytical methods and actions being taken were simple but effective. Close monitoring on reservoir pressure, water injection and ESP parameters will be needed as field surveillance. Integrated analysis with surface facility engineering should also be carried out in the future in regards to surface network, injection rate and reservoir pressure.

Achieving Injectivity Optimization and Zonal Rates Allocation through Multi-Zone Intelligent Completion Technology – A Field B Case Study from Offshore Malaysia

2021 ◽  
Author(s):  
Fuziana Tusimin ◽  
Latief Riyanto ◽  
Nurul Aula A'akif Fadzil ◽  
Nur Syazana Sadan ◽  
Asba Mazidah Abu Bakar ◽  
...  
Keyword(s):  
Real Time ◽  
Pressure Support ◽  
Water Injection ◽  
Injection Rate ◽  
Fluid Distribution ◽  
Successful Implementation ◽  
Reservoir Pressure ◽  
Well Completion ◽  
Ic Technology

Abstract Properly distributing injected fluid to provide injection conformance and reservoir pressure support into the respective zones of interest in mature fields can be challenging. This challenge, with injection fluid distribution, is typically encountered in fields with high contrast in permeability, reservoir pressure, and injectivity indexes among individual zones. Deployment of intelligent completion (IC) technology to address this challenge has rapidly increased, especially in multi-zone water injector wells, due to its capabilities for real-time reservoir monitoring and control of the fluid injected into multiple zones without requiring well interventions. This paper presents a case study of successful installation of IC technology in two water injector wells in Field B offshore Sarawak. The main objective of the IC implementation is to provide an efficient water-injection method for pressure support to the nearby oil producers and counteract the gas expansion through water injection at the flank area. Water injection implementation using the IC approach can further develop the oil rims and improve oil recovery in the particular reservoir to extend the field's production life. The custom tailored inflow control valve (ICV) design is robust enough to provide control of desired zonal injection rates. Each well was installed with two sets of ICVs to control the injection rate for each dedicated zone as well as a real-time permanent downhole gauge (PDG) to monitor the pressure drop across the ICV for zonal rates allocation / analysis. Apart from conceptual and detailed engineering study of the applied IC technology, proper downhole equipment selection and integration with surface facilities are also crucial to ensure successful implementation of the IC system as a holistic solution to achieve the injection objective. Post well completion installation, a water injectivity test was performed in both the selective and commingle injection modes. During selective injection testing, different positions of the ICV were manipulated and the water injection rate was monitored. This testing approach was performed for each ICV in the well. Post selective injection testing, commingle testing was conducted at the base 9,000 bwpd and maximum injection target of 18,000 bwpd, in which the testing was successfully executed to achieve the maximum well target injection rate. This paper shall discuss the reservoir management strategy through deployment of the water injectors, conceptual well completion design, and multi-zone injectivity requirements. Details such as ICV design using pre-drill and post-drill information, final well completion strategy, pre-installation preparation, installation optimization, execution of the IC deployment, injectivity test procedure, and results are discussed as well.

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