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Packers Plus
North Kuwait Jurassic Gas Experience of Expanding Multistage Completion Strategy for Managing Deep Tight Gas Development Challenges
Abdel-Basset, Mohamed (SLB) | Al-Otaibi, Yousef (Kuwait Oil Company) | Bloushi, Taha (Kuwait Oil Company) | Al-Dhafiri, Anood (Kuwait Oil Company) | Al-Mutawa, Majdi (Kuwait Oil Company) | Abdelbagi, Mamoun (SLB) | Hadi, Ahmed (Packers Plus)
Abstract North Kuwait Jurassic Gas asset has strategic importance for Kuwait production strategy as the only non-associated gas producing fields in Kuwait. This paper demonstrates the added value, experience, challenges and lessons learned of recent paradigm shift in Jurassic tight gas wells’ completion strategy from cemented liner to multistage completion. A successful expansion of Multi-Stage Completion (MSC) technology has been achieved on field level led by integrated team efforts since early 2020 to date. This helps to enhance overall well production potential, selective stimulation, overcome reservoir and intervention operations challenges, and early production delivery. The Jurassic gas asset produces mainly from deep high pressure and temperature, conventional and unconventional tight carbonate reservoirs. The recovery from such complex heterogeneous reservoirs is extremely challenging if conventional development strategies are applied. Due to the high reservoir tightness, permeability contrast among different flow units and dual permeability effect (matrix and natural fractures), well productivity potential significantly depends on the effectiveness of subsequent stimulation treatments of such complex heterogeneous reservoir to improve well productivity and connect the natural fractures. Selecting proper well completion is critical to overcome such reservoir challenges and ensure efficient acid stimulation treatments of such unconventional formations that need convenient diversion mechanism during the stimulation to enhance the productivity of each individual reservoir layer, and enable future flexibility of selective re-stimulation and reservoir management. The asset team has applied a step change in completion strategy to open-hole HPHT multistage drop-ball completions using state-of-the-art MSC technologies including closable frac ports, full 3.5in monobore post milling and debris sub to protect the MSC string during upper completion operations. This is to overcome such reservoir complexity, eliminate wellbore cleaning and multiple perforation intervention operations challenges and risks, eliminate cement quality uncertainties, improve overall cost, and fast track well delivery to production to meet asset production target by significantly reducing operation time from approximately one month of plug and perf technique to less than one week of continuous and less subsurface intervention operations. Total of 23 new Multi-stage completions were successfully installed in last 2 years including 4 systems in horizontal unconventional Najmah reservoir with overall good production results and significant improvement in selective acid stimulation (matrix and Fracturing), intervention operations efficiency and fast well delivery to production. Therefore, the asset plans to continue expansion in Multi-stage completion strategy. Based on gained experience, an integrated protocol for multi-stage candidate well selection, staging design and installation procedures workflow has been built by the integrated multidisciplinary team to ensure standard process across fields which can be used for application in other fields.
- Asia > Middle East > Qatar > Arabian Gulf > Rub' al Khali Basin > North Field > Laffan Formation (0.99)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > North Kuwait Jurassic (NKJ) Fields > Marrat Formation > Upper Marrat Formation (0.98)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > North Kuwait Jurassic (NKJ) Fields > Marrat Formation > Sargelu Formation (0.98)
The use of multilateral well designs and architectures have progressed significantly since the introduction nearly three decades ago. It has become the de-facto approach for unlocking incremental production performance and increasing drainage density in sands and limestone reservoirs. The tri-lateral well featured in this paper is a TAML Level-2 design with each 6000 ft lateral geosteered and completed by running openhole packers equipped with ball-activated frac-ports and sleeves on a non-cemented liner hanger system in the motherbore and drop-off systems in laterals-1 and 2. The pre-drill exercise encompassed technical considerations to determine from ---- reservoir type to well architecture, MSF technology, modelling for fracture stimulation effectiveness and well construction techniques --- to ensure success. Beyond established reservoir development strategies such as Maximum Reservoir Contact (MRC), the robustness and effectiveness of directed stimulation fluid to achieve frac stage deep acid stimulation at design pressures requires open-hole stage isolation technologies and devices that enable confirmation of completion of treatment operation. Additionally, working from bottoms-up, junction construction, debris management, securing well integrity during whipstock installation, window milling and whipstock retrieval are operational phases that pose significant challenge and risk to loss of well. The collaboration between Multilateral equipment design and engineering companies and Operators focus on simplifying junction construction, High frac pressure Open-hole packers as well as affirmative frac port open and close surface indicators. Innovative engineering solutions has produced advanced openhole isolation and completion hardware and material science developments are offering path clean-up and unobstructed reservoir fluid flow after stage stimulation. The integration of the latest multilateral construction technologies and techniques for ensuring missioncritical objectives leverages a multidiscipline collaboration approach to ensure well delivery and reservoir performance. Critical success factors discussed in this paper are, 1. Tri-lateral wellbore construction and recovery of junction construction devices, 2. Running and setting lower completion string, 3. Operating stage isolation devices and effective stimulation of each stage guided by advanced frac-stimulation modelling analysis and 4. Unrestricted reservoir flow through lower completion flow control devices. 2 SPE-213406-MS
- North America > United States (1.00)
- Europe (1.00)
- Asia > Middle East > Saudi Arabia (0.46)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock > Limestone (0.34)
First Time in Kuwait: Successful Hybrid Multistage Completion Accelerates Production of Najmah Unconventional Jurassic Gas Reservoir
Abdel-Basset, Mohamed (Schlumberger) | Bloushi, Taha (Kuwait Oil Company) | Al-Mutawa, Majdi (Kuwait Oil Company) | Al-Saeed, Abdulla (Kuwait Oil Company) | Al-Otaibi, Yousef (Kuwait Oil Company) | Hadi, Ahmed (Packers Plus)
Abstract North Kuwait Jurassic Gas asset development has strategic value of gas independency for Kuwait as it is the only non-associated gas producing asset. This paper will share the experience, added value, challenges and lessons learned from the successful implementation of first ever Hybrid 15k Multi-Stage Completion in Kuwait across Najma unconventional gas carbonate reservoir commingled with lower cemented liner completion in conventional Middle-Marrat tight carbonate reservoir. This completion configuration enables acceleration of selective stimulation and testing of Najma unconventional production potential in existing wells, and simultaneous comingled production from both reservoirs to maximize well production potential. The development of North Kuwait Jurassic deep unconventional gas carbonate reservoirs is key to compensate the production decline from conventional producing Middle-Marrat reservoir and to achieve the production target of Jurassic gas asset. The recovery from such unconventional reservoirs is extremely challenging if conventional development strategies are applied. Therefore, a dedicated full development plan applying integrated upstream and downstream technologies is important to achieve commercial production. The NK field development team has initiated a study to test the potential of unconventional Najmah formation in existing wells to evaluate the production potential and accelerate production from such reservoirs. The typical completion of Jurassic wells include Najmah reservoir in the 7-5/8″ cemented liner section followed by the Marrat reservoir completed in 5″ or 4.5″ cemented liner section. The multidisciplinary team efforts have yielded an innovative hybrid completion solution of 15K rated cased-hole ball-drop multistage completion across Najma reservoir layers and cemented liner across Middle-Marrat reservoir layers that allows selective commingled production of Middle-Marrat and Najmah with ensuring full selective stimulation potential across Najmah reservoirs through the multistage completion. Many completion design, operations and installation challenges were resolved to ensure mechanical isolation of lower depleted conventional reservoir before perforation the upper unconventional reservoir and running the multistage across it. This is to mitigate the challenges of high differential pressure of approximately 5,000 psi between the two reservoirs in completion phase to avoid high formation damage to the depleted Middle-Marrat lower reservoir plus well control during rig operation. This innovative hybrid completion has been installed successfully in one well as first time ever in Kuwait. Najmah and Middle Marrat reservoirs have been selectively stimulated and tested individually then commingled production from both reservoir as first time in Jurassic gas fields and Kuwait. PLT showed positive production contribution from Najma open frac ports and no cross flow among open reservoirs. There is a plan to expand such Hybrid completion to other candidates. This innovative completion configuration can be used in similar application for commingling production to minimize cost of new wells for different reservoirs.
North Kuwait Jurassic Gas Experience of Expanding Multistage Completion Strategy for Managing Deep Tight Gas Development Challenges
Abdel-Basset, Mohamed (Schlumberger) | Al-Otaibi, Yousef (Kuwait Oil Company) | Blushi, Taha (Kuwait Oil Company) | Al-Dhafiri, Anood (Kuwait Oil Company) | Al-Mutawa, Majdi (Kuwait Oil Company) | Abdelbagi, Mamoun (Schlumberger) | Hadi, Ahmed (Packers Plus)
Abstract North Kuwait Jurassic Gas asset has strategic importance for Kuwait production strategy as the only non-associated gas producing fields in Kuwait. This paper demonstrates the added value, experience, challenges and lessons learned of recent paradigm shift in Jurassic tight gas wells’ completion strategy from cemented liner to multistage completion. A successful expansion of Multi-Stage Completion (MSC) technology has been achieved on field level led by integrated team efforts since early 2020 to date. This helps to enhance overall well production potential, selective stimulation, overcome reservoir and intervention operations challenges, and early production delivery. The Jurassic gas asset produces mainly from deep high pressure and temperature, conventional and unconventional tight carbonate reservoirs. The recovery from such complex heterogeneous reservoirs is extremely challenging if conventional development strategies are applied. Due to the high reservoir tightness, permeability contrast among different flow units and dual permeability effect (matrix and natural fractures), well productivity potential significantly depends on the effectiveness of subsequent stimulation treatments of such complex heterogeneous reservoir to improve well productivity and connect the natural fractures. Selecting proper well completion is critical to overcome such reservoir challenges and ensure efficient acid stimulation treatments of such unconventional formations that need convenient diversion mechanism during the stimulation to enhance the productivity of each individual reservoir layer, and enable future flexibility of selective re-stimulation and reservoir management. The asset team has applied a step change in completion strategy to open-hole HPHT multistage drop-ball completions using state-of-the-art MSC technologies including closable frac ports, full 3.5in monobore post milling and debris sub to protect the MSC string during upper completion operations. This is to overcome such reservoir complexity, eliminate wellbore cleaning and multiple perforation intervention operations challenges and risks, eliminate cement quality uncertainties, improve overall cost, and fast track well delivery to production to meet asset production target by significantly reducing operation time from approximately one month of plug and perf technique to less than one week of continuous and less subsurface intervention operations. Total of 23 new Multi-stage completions were successfully installed in last 2 years including 4 systems in horizontal unconventional Najmah reservoir with overall good production results and significant improvement in selective acid stimulation (matrix and Fracturing), intervention operations efficiency and fast well delivery to production. Therefore, the asset plans to continue expansion in Multi-stage completion strategy. Based on gained experience, an integrated protocol for multi-stage candidate well selection, staging design and installation procedures workflow has been built by the integrated multidisciplinary team to ensure standard process across fields which can be used for application in other fields.
- Asia > Middle East > Qatar > Arabian Gulf > Rub' al Khali Basin > North Field > Laffan Formation (0.99)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > North Kuwait Jurassic (NKJ) Fields > Marrat Formation > Upper Marrat Formation (0.98)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > North Kuwait Jurassic (NKJ) Fields > Marrat Formation > Sargelu Formation (0.98)
Maximizing Stimulation Efficiencies in Offshore Multistage Completions, Black Sea, Romania
Grubac, Gabrijel (Seismos, OMV Petrom) | Conrad, Joel (Packers Plus) | Janiczek, Peter (OMV) | Alexandru, Dragomir (OMV Petrom) | Mcgarvey, Sean (Packers Plus)
Abstract This paper presents an analysis of the stimulation treatment design and operational efficiencies in the Black Sea. In greater detail, the paper focuses on how the stimulation design and each operational step has been optimized to save time, money and ensure an HSE driven completion methodology. An analysis was performed on the stimulation design and implementation approach looking at its evolution through a knowledge building and lesson learning process. The principal goal was to determine the most economical way to stimulate an offshore well without making any concessions to the reservoirs’ production or ultimate recovery. From the basics of well and frac design to completion optimization, effort was applied in analyzing ball launching procedures, frac spacing, logistical arrangements on the stimulation vessel and all other areas where there was potential to make improvements. Ultimately, an analysis of fluid displacements during flush was performed and deductions inferred. Past stimulation treatments were analyzed in an effort of better understanding the advantages and disadvantages in terms of production output of the wells. Similarly, an analysis of the completion approach and operational efficiencies showed the ability of pumping three stimulation stages a day. Considering that horizontal wells in the area are usually completed in six stages, a stimulation campaign would effectively be completed in 2 pumping days, 4 days total if no weather or operational delays are faced. Further improvements of this approach have been implemented in 2021 when six stimulation stages have been pumped in a single vessel ride. Applying the ball drop procedure offshore showed optimal results, as it is efficient in reducing downtime in between fracturing stages and in achieving proper isolation between stimulation zones. Likewise, with over flush being a concern throughout most of the stimulation population, certain cases in the Black Sea showed that over flushing did not adversely affect production of the wells with the production exhibiting ~15% above expected production rates post stimulation. In conclusion, the authors believe that the operational efficiencies achieved in the Black Sea are transposable in other offshore environments and successful cost cutting can be achieved by sound engineering and logistical decisions. The approach and results are beneficial in understanding where the economics are positively impacted in multistage stimulation treatments in the offshore environments, hence ultimately improving the rate of return.
- North America > United States > Texas (0.28)
- Asia > Middle East > UAE (0.28)
Paradigm Shift from Cemented Completions to Multi-Stage Completion Strategy for Managing Tight Gas Development Challenges
Abdel-Basset, Mohamed (Schlumberger) | Al-Otaibi, Yousef (Kuwait Oil Company) | Al-Saeed, Abdulla (Kuwait Oil Company) | Blushi, Taha (Kuwait Oil Company) | Fidan, Erkan (Kuwait Oil Company) | Al-Mutawa, Majdi (Kuwait Oil Company) | Abdelbagi, Mamoun (Schlumberger) | Hadi, Ahmed (Packers Plus)
Abstract The development of North Kuwait Jurassic gas assets has strategic importance for Kuwait's production strategy as the only non-associated gas-producing field in Kuwait. This paper demonstrates the benefits, challenges and lessons learned of the recent paradigm shift in Jurassic tight gas wells’ completion strategy from cemented liner to multi-stage completion. Successful expansion of Multi-Stage Completion (MSC) technology is achieved at the field level led by the integrated team efforts in 2020/21, despite challenging constraints of COVID-19. MSC's help to enhance overall well production potential, overcome reservoir and intervention operation challenges, and allow early production delivery, which is a key factor to achieve a strategic asset production target of 70-80% by 2024/25. Many technical and logistic challenges were experienced during first installations of which the relevant learnings will be shared in this paper. The Jurassic gas asset produces mainly from deep high pressure and temperature, conventional and unconventional tight carbonate reservoirs. The recovery from such complex heterogeneous reservoirs is extremely challenging if conventional development strategies are applied. Therefore, a dedicated full development plan applying integrated upstream and downstream technologies is important to achieve the strategic production target. Due to the excessive Jurassic carbonate reservoir tightness, permeability contrast and dual permeability effect (matrix and natural fractures), well productivity potential significantly depends on the effectiveness of subsequent stimulation treatments of such complex heterogeneous reservoirs to improve well productivity and potentially connect with natural fractures. Selecting proper well completion design is critical to overcome such reservoir challenges and ensure effective acid stimulation treatments for the mix of conventional and unconventional formations that need convenient diversion mechanism during stimulation to enhance the productivity of each individual reservoir flow unit and enable selective future flexibility of re-stimulation and reservoir management. The asset team has recently applied a step change in completion strategy to open hole multi-stage ball drop completions using state of the art MSC technologies including closeable frac sleeves, full 3.5-in monobore ID post frac sleeves milling and debris sub enclosure to protect the MSC string during casing tie-back operations. This is to overcome reservoir complexity, eliminate wellbore cleaning and decrease the challenges and risks that accompany multiple perforation intervention operations. As well as, eliminate cement quality risks and uncertainties, improve overall cost, and fast track well delivery to production to meet asset production targets by significantly reducing operation time from approximately one month for plug and perf techniques to less than one week when using continuous and less subsurface intervention operations. Recently, a total of 13 new MSC installations and subsequent multi-stage stimulations were achieved in seven months, fromQ3-2020 to Q1-2021, with positive overall production results, significant improvement of intervention operation efficiency and faster well delivery to production. This paper will describe the details of progress to date, and the plan forward for optimization and new technology trials to further improve well performance.
- Asia > Middle East > Kuwait (1.00)
- Asia > Middle East > UAE > Abu Dhabi Emirate > Abu Dhabi (0.15)
- Asia > Middle East > Qatar > Arabian Gulf > Rub' al Khali Basin > North Field > Laffan Formation (0.99)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > North Kuwait Jurassic (NKJ) Fields > Marrat Formation > Upper Marrat Formation (0.98)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > North Kuwait Jurassic (NKJ) Fields > Marrat Formation > Sargelu Formation (0.98)
Abstract Since the beginning of drilling for oil, improving efficiency and reducing the cost of hydrocarbon recovery have been key issues when designing a well. Since then, new methods and techniques have developed the industry. One of the most critical events in the oil and gas industry was the invention of the liner hanger. Since Liner Hangers are utilized as the primary solution to wellbore construction, they have been designed with such requirements in mind. This paper will deliver an insight to an innovation life cycle where a stakeholder collaborated together to successfully deliver, plan and complete the first 15,000 PSI, 400 °F high pressure- high temperature (HPHT) Liner Hanger designed to overcome the operational obstacles that conventional liner hangers have when deployed with Multistage Frac (MSF) completion systems but still allows for successful operations in cemented completions. This liner hanger technology has been run in different parts of the world and has proven since the beginning that with all the features included in the designed stages.
Multilateral Multistage Hydraulic Fractured Offshore Wells; A New Trend in Completion Design and Optimization for More Effective Field Development
Bocaneala, Bogdan (OPECS) | Norris, Mark (OPECS) | Conrad, Joel (Packers Plus) | Tomlins, Andrew (OMV) | Bramald, James (Ithaca Energy) | Airnes, Jamie (Ithaca Energy)
Abstract Recently two multilateral horizontal wells have been completed offshore using dedicated multistage hydraulic fracturing completions. The first well, located in the Central North Sea (referred to as ML-CNS), was stimulated using acid fracturing; while the second well, located in the Black Sea (referred to as ML-BKS), was stimulated using proppant fracturing. This paper presents the different drivers, challenges and lessons learned for each well while emphasizing the well construction and stimulation methodologies developed for the different reservoirs and field characteristics. The field development drivers for drilling and completing these offshore hydraulic fractured multilateral wells, a first of their kind globally, was different for each case. The objective of the first project, initially considered uneconomic, was to engineer a technical solution for completion and production of two separate reservoirs with only one subsea well. The second project was seeking to optimize infill drilling from the last available slot on the offshore platform to maximize reservoir contact and production in the same reservoir. ML-CNS was a TAML Level 2 completion with a 14-stage, 5 ½" multistage completion run in each lateral and set-up for sequential acid fracturing. Operationally, the first lateral was drilled and stimulated, followed by the drilling and stimulation of the second lateral, using the drilling whipstock to navigate through the multilateral junction. ML-BKS was a TAML Level 3 completion that had a 6-stage, 4 ½" multistage completion installed in each lateral, which were proppant fractured following a sequence designed to minimize the jack-up rig time required. Both legs were drilled and completed prior to starting the stimulation, access to either lateral was achieved with the existing workover unit on the platform by manipulating a custom designed BHA. The lessons learned from the first project executed in the North Sea were able to be transferred and applied to the second project in the Black Sea to allow for a more efficient and confident completion solution. Led by varying economical and regional constraints, the key factor for both wells centered on delivering operationally simple and reliable multilateral completion designs to economically meet the field development strategy in place. To the knowledge of the authors and following subsequent literature research, both wells are a worldwide first for an offshore multilateral well completed with multistage acid fracturing and multistage proppant fracturing, and together they represent a new trend in cost-effective offshore field development through well stimulation. The successful case studies for both wells with the combined analysis of the benefits, challenges, and lessons learned will provide a guide and instill confidence with operators who find this approach beneficial with a view to applying it in other assets.
- North America > United States (1.00)
- Europe > North Sea (0.90)
- Europe > United Kingdom > North Sea > Central North Sea (0.47)
- Europe > United Kingdom > North Sea > Central North Sea > Central Graben > Greater Stella Area > Block 30/6a > Stella Field > Stella Ekofisk Formation (0.99)
- Europe > United Kingdom > North Sea > Central North Sea > Central Graben > Greater Stella Area > Block 30/6a > Stella Field > Stella Andrew Formation (0.99)
- Europe > United Kingdom > North Sea > Central North Sea > Central Graben > Greater Stella Area > Block 30/6a > Harrier Field > Tor Formation (0.99)
- (15 more...)
Abstract Saudi Aramco Unconventional Production Engineering Division currently performs multistage propped fracturing operations using cemented plug and perf completions, to target tight gas reservoirs requiring stimulation. To improve operational efficiency, eliminate wireline intervention and coil tubing milling operations, the decision was made to test an openhole multistage fracture system (OH MSF). This came with the challenge of ensuring adequate reservoir contact, comparable to the cemented plug and perf operations, where 21 perforation clusters, in average, are targeted. The OH MSF technology chosen consists of multiple frac ports per stage with high pressure mechanical packers to isolate each stage and slip-on oil swell packers, to isolate the individual frac port within a stage. This new method of diversion within the compartment itself helps to ensure that small variances in pressure between nozzle ports are isolated preventing the fracture operation within a stage from consolidating to a single-entry point. Like standard ball drop sleeve systems, the OH multiple entry frac sleeve system uses progressively increasing diameter balls to open each stage. One single ball will open all the ports in one stage simulating multiple clusters per stage. This allows for an increase in reservoir contact when stimulating large openhole lengths. Case Study Well-A was completed with six multi-entry stages, three entry points per stage, and one toe stage utilizing a hydraulic port resulting in a total of seven stages and 19 frac sleeves. The isolation plan for this well consisted of mechanical packers between the main nine stages and slip-on constrictors between the individual ports within each stage. Each fracture port was engineered with three jets of 0.563 in. hole diameter as part of the limited entry design. All the fracture stages were performed as per design. The initial production response was better than offset wells completed with plug and perf technique. A production log suggests contribution from 75% of each individual jet, indicating the proper diversion was achieved. Using a seven-stage openhole system yielded to 17 effective fractures contributing to production. By utilizing OH Multiple Entry MSF system technology for limited entry fracturing, Saudi Aramco has improved reservoir productivity and operation efficiency. This is the first time an openhole multistage fracturing system combining mechanical and constrictor swell packers has been deployed to promote limited entry diversion. This qualified and field-tested novel completion methodology ensures proper fracturing diversion between frac-ports located within the same stage. The benefits of this technology include improved reservoir contact, operation efficiency, cost reduction and placement improvement.
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > Asia Government > Middle East Government > Saudi Arabia Government (0.96)
Harrier Development: Successful Implementation of the World's First Offshore Multilateral Installation with Staged Acid Fracturing Performed on Both Laterals
Scott-Rampersad, Ria (Schlumberger) | Norris, Mark (OPECs) | Carval, Rafael Guedes (Schlumberger) | Airnes, Jamie (Ithaca Energy) | Bramald, James (Ithaca Energy) | Oberhofer, Rob (Packers Plus)
Abstract With a suppressed hydrocarbon sector over the past few years, operators, service providers and ancillary companies alike have been strongly challenged to collaborate, where feasible, on field development solutions which offer greater economies of scale and efficiency by reducing operational time and cost. This paper details the evolution of the Harrier field development plan (FDP) in the context of innovation within completion and stimulation treatment design which has successfully created value for this North Sea gas operator. Originally, the project plan comprised of two development wells, each accessing separate chalk gas reservoirs - Ekofisk and Tor which were approved by the UK Oil and Gas Authority in 2012 under the Stella and Harrier FDP, with an estimated development cost of USD 250 million. During the conceptual phase, the project economics were not attractive even in a high oil price environment. Services providers were then invited to provide alternative solutions to significantly enhance the investment appeal of this opportunity with the aim of reducing capital and operating expenditure while enhancing both field recovery and accelerated production. One such provider was successful with the proposition of a revolutionary contraction of the FDP with a unique design concept of a single well development terminating in a dual lateral with each leg targeting a separate reservoir in which fourteen acid stimulation stages per leg were planned to greatly enhance productivity. After several months of intensive collaboration, the optimized well design was completed and the project was sanctioned with field development cost reduced by a full 50%. The paper provides an overview of the stimulation design, based on the reservoir challenges encountered and the progression of the completion design explored, into its final fit for purpose realisation. Results in relation to achievement of well objectives, service delivery, change management during the execution phase and most significantly overall well performance are also provided. The objective of this paper is not only to demonstrate the value created to the field operator, but also to illustrate how planning and developing a unique solution was strongly influenced by a cost sensitive environment for efficiencies gained, with regards to risk management and mitigation, along with contingency planning. Furthermore, through a multi-segment integrated approach experience, numerous lessons learnt and best practices were harnessed for use when venturing on similar projects championing technical innovation under economic and resource constraints.
- Europe > United Kingdom > North Sea > Central North Sea > Utsira High > PL 006 > Ekofisk Formation (0.99)
- Europe > United Kingdom > North Sea > Central North Sea > Central Graben > Block 30/7a > J-Block Field > Joanne Field > Judy Field (0.99)
- Europe > United Kingdom > North Sea > Central North Sea > Central Graben > Block 30/7a > J-Block Field > J-Block Field > Judy Field (0.99)
- (21 more...)