bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Reversed Geo-Dynamic Approach for Brownfield Rejuvenation
Authors: Mudi Ibrahim Mahmoud , Hollmann Gregor 
Published: November 2016

Abstract
Brownfields are typically characterized by enormous amounts of data that include various technologies and disciplines enabling highly detailed and probabilistic models. However, data abundance often puts a threat to evaluation effectivity and to a correct identification of key controlling factors. In the E&P industry, many "sequential" approaches exist for mature field evaluation, where "static" and "dynamic" data are disconnected during the process.
The main objective of this paper is to present a new and fully integrated workflow for brownfield re-evaluation and rejuvenation. Our "reversed" Geo-Dynamic Field Modelling (GDFM) relies on simultaneous cross-discipline interaction to guarantee data consistency and is based on a full dynamic/static data coupling at a very early stage. The GDFM workflow reverses key elements of the discipline driven sequential workflow. Production and pressure data analysis comes first, not last. Field diagnosis, identification of flow units, well test re-analysis, petrophysical and geological re-interpretation are combined in cross-disciplines model constraints. These include identification of major field issues, data reliability rankings, uncertainty/certainty and impact analysis, parameter trends etc. Seismic (re−) interpretation acts as the first main integration step, honoring all available data already during horizon and fault mapping. This directly ensures a fully integrated model that – combined with seismic attribute analysis - forms the basis for static reservoir modelling and dynamic simulation.
A field example illustrates the benefits of the GDFM: a consistent history match at considerably reduced iteration time while focusing on the key controlling factors. GDFM increases model accuracy and confidence because all data sources are incorporated, honored and cross-discplinary quality controlled early in the process. The applied workflow supports uncertainty/certainty analysis for history matching, enhances the geologic model, improves the reservoir properties distributions and presents a solid base for the dynamic simulation. Though a number of minor iterations between the main work packages are still required, the case study shows that full cycle repetitions between static and dynamic modelling are avoided, which considerably reduces the time requirements of the subsurface re-evaluation and improves remarkably the studiy results.
Strategies and Best Practices for Selecting Reservoir Sector Schemes to Manage Offtake in a Waterflood
Authors: Obeta Chukwudi , Al Dhanhani Omar , Tee Aaron , Al Shehhi Budoor Hasan , Qi Zili , Li Dachang , Brantferger Kenneth 
Published: November 2016

Abstract
Most reservoirs, especially in carbonate systems, are characterized by heterogeneities in pore systems, permeability, diagenetic imprints, faults and lineaments, fractures, fluid systems and displacement parameters. These variable set of conditions may result in significant differences in in-place volumes as well as life cycle production behavior from different regions of the reservoir when subjected to the same depletion scheme.
To guide and control the reservoir life cycle development and management, and to leverage the full benefit of tailoring specific depletion designs suitable for specific areas of the reservoir, the asset owner has instituted a new set of guidelines on reservoir sectorization to govern all operated assets. Reservoir Sectorization could be defined as the process of outlining regions of the reservoir defined by prominent geologic features (structural, stratigraphic, diagenetic, fluid contacts, etc.) that control reservoir and well performance within which production targets can be defined, analyses conducted and surveillance plans designed.
A large offshore carbonate reservoir operated by ZADCO, which is the subject of this paper, is impacted in several ways by the aforementioned geological complexities and was deployed as a pilot to test and fully implement the new guidelines on reservoir sectorization. Previously, the existing sector pattern for the candidate reservoir was based on a five-spot flood scheme which is no longer suitable in view of the change to the current field development concept of artificial islands and long MRC wells. Therefore, in addition to compliance with the new guidelines, the key business driver for re-sectorization is to ensure sector geometries that support a line drive system, avoid wells intersecting sector boundaries and provide flexibility to adapt well placement to evolving field development challenges.
Advanced integrated workflows (analytical and simulation) were implemented and several sectorization schemes designed (1 or "no" sector, 3 sector, 4 sector, 4 quad, and 5 sector-patterns), assessed and benchmarked against defined criteria for success. Further optimizations through numerous dynamic model sensitivities led to adoption of a particular scheme that best complies with new guidelines on sectorization as well as meet the life cycle production target for the reservoir.
This paper highlights the workflows implemented, the challenges encountered and the proposed best practices in working and adopting a reservoir sectorization scheme that best enables sustainable production and maximum recovery within the constraints of the asset owners' guidelines.
Using Cf-252 as a Short Half-Life Neutron Source Provides a Safe and Reliable Porosity Alternative When Drilling in a Middle East Carbonate Reservoir
Authors: Al Arfi Saif , El Shahat Ayman , El Farouk Omar , Mostafa Hassan , El Kholy Mohamed , El Komy Mohamed 
Published: November 2016

Abstract
UAE environmental regulations call for minimizing exposure to radioactive waste while drilling. In depleted carbonate reservoirs, the low radiation energy, short half-life Californium-252 (Cf-252) neutron source provides a "fit for purpose" replacement to the high radiation energy, long half-life americium-beryllium (Am-Be) neutron source. With the much shorter half-life time Cf-252 neutron source, ADCO could minimize the associated liability of getting stuck downhole by eliminating the use of high energy radioactive sources with 430 year half-lives.
The Cf-252 sources emit neutrons as a result of spontaneous fission with a probability of about 3%. One gram of Cf-252 yields about 1,012 neutrons per second (n/s), which is a much higher neutron yield than Am-Be sources. A typical Cf-252 source with an activity rating of 20 mCi emits about 108 n/s compared to 16 CI from Am-Be. This fission reaction has a half-life of 2.6 years compared to 430 years for Am-Be, which means that the neutron output of the source drops by a factor of two every 2.6 years. However this reduces the useful life of the source to somewhere between 5 and 10 years. Although higher-output Cf-252 sources can be obtained to lengthen the useful life of the source, cost and safety may be issues.
To prove the effectiveness of the new source, it was decided to run the Cf-252 back-to-back with the Am-Be source. By running both sources in the same bottomhole assembly (BHA), the quality of the Cf 252 could be validated by comparing the back-to-back measurements generated from both Cf-252 and Am-Be sources. The data was compared while wiping in, wiping out, and drilling. The Cf-252 source tool was placed on the top of all other tools in the BHA in recorded memory mode. The data acquired while drilling showed a slight separation between Cf-252 porosity readings and the readings from the tool using an Am-Be. This is due to the varying formation exposure time experienced by the tool with the Cf-252 source, an invasion effect observed due to the slow rate of penetration (ROP). There is also much closer agreement between the two neutron measurements while wiping out.
This case study demonstrates the value of using a low radiation energy Cf-252 source compared to using high radiation energy Am-Be source when drilling in a depleted reservoir. A lost-in-hole Am-Be source had to be fished, which prevented the operator from plugging the well. However, using a Cf-252 source would minimize such liabilities, making the plug back procedure easier with significant savings in time and money.
Hydraulic Fracturing Application of New Seawater-Based Clean Fluid
Authors: Prakash Chetan , Raykov Tzoni , Koalsa Bartlomiej , Belakshe Ravikant , Janiczek Peter 
Published: November 2016

Abstract
Seawater-based fracturing fluids are favorable in offshore locations because of the readily available seawater. This can minimize or even eliminate costly vessel trips necessary to transport fresh water to rig sites, while also reducing rig downtime. This paper presents the development of a low-residue fracturing fluid that uses seawater as a base fluid and also presents the results of successful field applications.
This seawater-based fracturing fluid uses a low-residue polymer crosslinked with zirconium that has a pH of less than 10 to minimize damage and residue encountered using other fluids. The fluid was tested for rheological properties, proppant-carrying capacity, retained permeability, and compatibility with formation fluid. To improve timing and efficiency of operations, a multistage fracturing completion was used wherein each fracture sleeve was opened by dissolvable balls. Three wells were treated in the offshore Romanian Lebada fields. Well A comprised high sandstone content. Wells B and C comprised a higher limestone content but contained too much clay and sandstone for an acid fracturing treatment. Both wells exhibited a moderate-to-high number of natural fractures. Because of moderate permeabilities in the range of 0.1 to 2 md, crosslinked fluid was used in the pad and subsequent proppant-laden stages.
During development evaluations, the fluid remained stable for approximately 1 hour at 325°F with a gel loading of 6 kg/m3 (50 lbm/1000 gal) The thermal stability of the fluid system was improved when compared to the alternative hydroxypropyl guar (HPG) fluid. A delayed crosslinker was used to maintain low-friction pressure during the treatment. No scale formation was observed. The target reservoir temperature was 199°F. Additional testing optimized gel loading at 3.6 kg/m3 (30 lbm/1000 gal). The fluid suspended the proppant for approximately 2 hours. Less than 1% residue was formed after fluid breakdown, which was much lower than the residue generated by the HPG fluid. A regained permeability of 92% was obtained from a sandstone core, demonstrating the low-damaging nature of the fluid. The broken fluid was fully compatible with crude oil and completion brine.
Twenty total stages of hydraulic fracturing operations were designed and executed successfully in the three horizontal wells. A 16/20-mesh resin-coated proppant (RCP) was used at a maximum concentration of 720 kg/m3 (6 lbm/gal) during the tail stage. A total of 1533 tonnes (~3.38 million lbm) of proppant was pumped in 5915 m3 (~1.56 million gal) of crosslinked fluid.
The seawater-based fluid properties present an innovative approach for addressing the water requirement issue for offshore stimulation operations. This fluid is an excellent candidate for fracturing operations and can help operators maintain low costs per barrel of oil equivalent (BOE).
Dynamic Simulation of Major Kick for an HP/HT Well in Western China
Authors: Zhao Haiyang , Li Shuanggui , Jia Xiaobin , Sun Guo Hua , Yu Zhong , Wang Ke , Chen PeiLiang , Yu Zhong , Xu YanDong , Long Wu , Xu Liru , Gao Wei , Qiu Kaibin 
Published: November 2016

Abstract
As the search for petroleum has moved into the high-pressure/high-temperature (HP/HT) environment, the well control problems have continued to increase in complexity due to the small pressure margins and the large temperature-driven variations of mud properties often seen. Recently in western China, a major kick was encountered while drilling to 7874 m with 16-ppg water-based mud in an HP/HT well. Killing of the well was attempted but was not successful. After that, the drillstring broke near the top of wellbore. As a contingency action, the operator abandoned the plan for further killing and put the well into production through diverting the kick to the production pipeline. Many unknowns, which were unsolvable by conventional perceptions, were still intriguing the operator and might be issues in further drilling operations in this field. These unknowns include: (1) Why was the well pressure constant before the gas reached the wellhead while the well was shut-in for almost 2 days? (2) Where was the gas top during shut-in? (3) Why did the killing attempt fail? (4) What killing parameters should have been used in the killing attempt?
To address these unknowns and provide solid guidance for further drilling operations, simulation of the gas kick development and well killing was conducted using a dynamic hydraulic and well control simulator powered by transient multiphase flow model.
Through integration of existing well and reservoir data, the dynamic simulation was able to history match the observed wellhead pressure, casing pressure during the shut-in, and killing operations. The simulation showed that the killing pump rate was not adequate to kill this well for the given gas kick in the wellbore. The dynamic simulations successfully revealed the reason for the gas suspension in the wellbore while shut-in, predicted the gas top, and identified the required pumping rate for a success killing. The simulation also disclosed the root cause of the drillstring failure.
This case study highlights the importance of dynamic simulation during the well engineering design and before any attempt of well killing to improve chance of success for well control and safety of drilling operations.
Case Study on Remotely Operated Intelligent Plugs to Eliminate Multiple Wireline Runs in Offshore Completions
Authors: Suresh Zac Arackakudiyil , Nguyen Linh , Kannan Bharathwaj , Jung Oh Huyn , Seok Yi Jae , Luu Truyen 
Published: November 2016

Abstract
This paper introduces a novel application of intelligent completions using remotely operated intelligent plugs that can eliminate multiple wireline runs. This case study outlines completion of two wells in offshore Vung Tau, Vietnam using intelligent plugs. The plugs were used to test tubing, set the packer, and later act as deep-set barriers for christmas tree installation.
The wells were completed with two intelligent plugs preinstalled and run-in-hole (RIH) open. One was installed above the production packer and the other below. Use of such intelligent plugs allowed opening and closing the plugs remotely; this feature is attributed to the plugs' onboard decision-making electronics to monitor well conditions programmed to either open or close whenever a specified condition (known as a trigger) is detected. This allowed the operator to communicate to the tool remotely from the surface using applied-pressure commands.
The upper plug was closed initially to test the tubing string. It was later opened and the lower plug was closed to set the packer. The lower plug was then opened to test the packer. Both plugs were later closed to act as barriers when the blowout preventer (BOP) was removed and the christmas tree was installed. Both plugs were then opened and pulled out of hole (POOH) on wireline.
The use of remotely operated intelligent plugs helped the operator successfully eliminate eight wireline runs, saving approximately 15 hours of rig time. Considerable monetary savings were gained by removing intervention runs. Additionally, health, safety, and environment (HSE) risks associated with rigging up and running wireline were also eliminated in this case.
The industry is striving to perform completion and intervention activities in a safer and more economic manner. This case study of remotely operated intelligent plugs can be a timely addition to existing intelligent completion solutions.
Control of Hydraulic Fracture Height Growth Above Water Zone by Inducing Artificial Barrier in Western Desert, Egypt
Authors: Salah Mohamed , Gabry Mohamed A. , ElSebaee Mohamed , Mohamed Nelly 
Published: November 2016

Abstract
Hydraulic fracturing is frequently used to create enhanced wellbore connectivity to enable tight reservoirs to produce hydrocarbon. Many factors can be considered as risks to the success of fracturing operations. One of the risks arises in reservoirs that are close to a water-bearing zone. The risk of fracture growth into the water zone limits the stimulation options and eliminates the chances of using hydraulic fracturing treatment to improve well productivity, thereby restricting the well's future production and often resulting in lost recoverable reserves. In the Western Desert of Egypt, two wells were to be fracture stimulated with a risk of propagating into a nearby water zone. The productive pay of low-permeability reservoirs is separated from underlying water zones by a weak or no stress barrier. The proximity of the water zone to the hydrocarbon-producing zone varied from 20 to 40 ft, and containing the fracture height in such well conditions to prevent the fracture propagating into the underlying water zone becomes a serious challenge. This can jeopardize the post treatment well productivity. It therefore becomes necessary to prevent fracture height propagation from growing into the adjacent water zone.
This case study presents a novel hydraulic fracturing technique, applied for the first time in Egypt's Western Desert that controls fracture height growth in the absence of in-situ stress contrasts. This technique places an artificial proppant barrier below the pay zone, close to the water-oil contact, creating high resistance to fluid movement and restricting pressure transmission, thus arresting unbridled vertical height growth of fractures. These barriers are created prior to themain fracture treatment by pumping heavy proppant slurry at fracturing rates carried in a fracturing fluid loaded with high breaker concentrations. The high breaker concentration breaks the gel fast, thus allowing the proppant to settle quickly to the bottom of the created fracture. The results from the application of this newly applied dual fracturing treatment technique have been overwhelming, with a 12-fold increase in production with no increase in water production. The application of this technique resulted in an increase in the net pressure at the end of main fracturing treatment indicating fracture containment within the zones of interest. The minifracture analysis, stress profile calculation, fracture geometry characterization, and no water breakthrough after the treatment support the fracturing design.
Automated Technical Workflow for Smart PVT Program Design and Quality Control for Efficient Fluid Characterization
Authors: Mawlod Arwa , David Richard Mohan 
Published: November 2016

Abstract
PVT data is critical for fluid characterization and EOS modelling, which in turn is the key to estimate the initial hydrocarbon volumes in place, predicting reservoir dynamic behavior and production forecasting. Hence, ADCO gives high importance to have well distributed and high quality PVT data across its different reservoirs.
There are various parties involved in planning and execution of PVT studies. There have been problems associated with PVT studies workflow such as poor scope of work, data quality issues, lost historical PVT data that affects the fluid characterization and EOS modelling. In addition, there are inefficiencies due to lack of coordination amongst various activities and parties involved in the PVT studies workflow.
In this regard, ADCO embarked on standardizing and automating the entire process from PVT analysis requisition through technical data validation and archiving towards building an integrated PVT e-catalog. In our previous SPE paper (SPE-172832) we discussed our challenges, implementation strategy, and functional design phase of the project including the roadmap. In this paper discussed the progress and achievements made by ADCO towards establishing PVT intelligence Solution and integrated PVT e-catalog. The Solution enables the users to efficiently design, PVT analysis and sampling programs for a variety of fluids types and different studies such as routine, enhanced oil recovery studies, asphalltene studies. It also enables the user to perform consistent and standard validation for the PVT data during project execution
The standard scope of work for various PVT studies is predefined based on the industry standards and well defined business logic. The workflow intelligently guides the users to build the right scope of work for PVT analysis and sampling based on the business objectives and reservoir information. The solution has functionality to technically validate the data delivered by the contractors in stages through approval workflows. This is done through a smart quality control tools which is supported by business rules for various tests that enables a semi-automatic quality control for the measured PVT properties. Finally the workflow enables the users to systematically archive quality data in an integrated PVT e-catalog. The e-catalog comprise of PVT database and functionalities for quick search of PVT data across ADCO fields and reservoirs.
PVT intelligence enables the users to quickly and independently create high quality PVT sampling and analysis Scope of Work through an automated workflow. The workflow reduces the user effort and uncertainty in manual quality control for the data delivered by the laboratories and resolve data anomalies at the right time. The intelligent functionalities shall improve the quality of the PVT e-catalog which in turn enables better engineering models and calculations for Efficient Fluid Characterization.
Economic Analysis of Dimethyl Ether Production in Indonesia as Alternative Solution for LPG Demand
Authors: Kurniawan Temmy Surya , Pertamina PT , Siagian Utjok W. 
Published: November 2016

Abstract
In line with economic development and population growth, Indonesian energy demand has been increasing. In the past 10 years, growth of demand is around 5% per annum, on average. Indonesian energy demand is supplied primarily by oil (47%). As domestic oil resource is no longer sufficient to supply domestic demand, Indonesia energy policy objective is to move away from oil by promoting utilization of more abundantly available energy resources such as natural gas. Java Island is nation's energy demand center meanwhile Indonesian natural gas resources are located in many regions outside Java Island.
Connecting natural gas fields to the demand centers in Java would require massive investment to build gas transport and distribution infrastructure. Therefore, alternative ways of converting gas into denser energy carrier and transporting the energy using non-pipeline facilities (ships, trucks) to transport the gas to customers need to be developed. LNG and CNG are usually appropriate for large natural gas reserves and they have been developed in Indonesia. In the other hand, Indonesia still has many untapped small-medium size gas reserves. Small-medium size gas reserve (0.5-1 Tcf) is sufficient to support dimethyl ether (DME) development which could be another option for converting natural gas. DME has similar properties with LPG so it can substitute LPG. It can also substitute diesel oil used in trucks and buses. Demand for these fuels will continue to increase in the future.
This paper presents the feasibility of DME development which is assessed using wellhead netback price of gas as feasibility indicator. The netback price is calculated using the price of fuels to be substituted by the gas (in this case: LPG) as references. The basic question of this study is what is the minimum gas price at wellhead that satisfy DME project investor's economic criteria when the gas is converted to DME and the DME is to substitute LPG consumption. The minimum acceptable rate of return (MARR) as economic criteria is set at 16%.
In addition to feasibility analysis, this study also evaluates Indonesian regulatory readiness for DME development and benefits that could be gained by Indonesia as well as its risk for the implementation.