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Collaborating Authors
Open hole/cased hole log analysis
Abstract The use of pressure transient data in the field of Formation Testing in efforts to describe productivity and permeability of reservoirs is considered mature technology, particularly when applied to data collected through production testing. The extension of this technique to data obtained using Wireline Formation Testers, where either a single probe or a straddle packer is used to propagate a pressure pulse into a reservoir, has been gaining momentum in the industry over the past decade, however the integration of these outputs with other measurements of rock and fluid data is not always straight forward. This paper presents different methods of using pressure transient data from Wireline Formation Testers such as quantitative permeability determination, identification of permeability discrepancies in homogenous clastic formations, upscaling of permeability in a complex stacked reservoir and comparison of Wireline Formation Tester and conventional well test derived permeabilities. Additionally, this paper highlights the challenges one faces while planning, acquiring and interpreting pressure transient data from Wireline Formation Testers, as well as the importance of real-time monitoring and control of data.
- Asia (1.00)
- North America > United States > Texas (0.28)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Formation test analysis (e.g., wireline, LWD) (1.00)
High Resolution Saturation Analysis in Nile Delta Turbiditic Sands from Imaging Tool Resistivity and NMR in Oil-Based Mud
Salah, A.. (Belayim Petroleum Company) | Sabra, M.. (Belayim Petroleum Company) | Said, M.. (Belayim Petroleum Company) | Van Steenes, M.. (Schlumberger) | Haddad, E.. (Schlumberger)
Abstract Porosity, water saturation, and net-to-gross evaluation can be challenging in thinly bedded sands. The use of standard induction resistivity for formation evaluation can lead to the overestimation of water saturation. This work explores the following options to improve formation evaluation in these conditions: the use of high resolution density and nuclear magnetic resonance (NMR) data to improve porosity vertical resolution; the use of high-resolution resistivity from an oil-based-mud microresistivity imaging tool in improving the saturation computation (Sw); and the comparison of imaging tool resistivity-based sand count and NMR-based thin-bed fraction. Using high-resolution porosity inputs from density and NMR provided a porosity curve with a better vertical resolution to match the high resolution resistivity from the imaging tool. It also identified additional productive thin beds compared to the standard resolution outputs and allowed computation of a high-resolution irreducible water saturation. The induction-based Sw is strongly affected by shoulder bed effect and overestimates Sw by approximately 10 to 15%. The high-resolution curve from the imaging tool was used as an input into the Sw computation, which was made possible by shallow oil-based mud (OBM) invasion. This approach gave good results in beds thicker than 6 in., where Sw from the imaging tool matches the irreducible water saturation computed from NMR, giving 20 to 30% Sw. A thin-bed fraction curve was computed from the NMR data. It shows a good match with the image-based high resolution- sand count and the image features, demonstrating that NMR and the imaging tool are equally able to identify and quantify thin beds, even though they have different vertical resolutions. This study showed that the microresistivity imaging tool and NMR are essential tools to characterize thinly bedded reservoirs.
- North America > United States > Texas (0.47)
- Africa > Middle East > Egypt > Nile Delta (0.41)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.71)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.33)
- Geophysics > Borehole Geophysics (1.00)
- Geophysics > Seismic Surveying > Borehole Seismic Surveying (0.47)
Effect of Petrophysical Re-interpretation on Matured Fields' Development Planning and Producing Reserves Boosting Up in Abu El Gharadig Basin, Western Desert, Egypt.
Rizk, Mahmoud (Sahara Oil and Gas (SOG)) | Rafik, M.. (Sahara Oil and Gas (SOG)) | Ell-Behiry, A (Sahara Oil and Gas (SOG)) | Abdel-Nabi, M.. (Sahara Oil and Gas (SOG))
Abstract West Qarun (WQ) and Abrar fields are located in Abu El Gharadig (A/G) basin in the Egyptian Western Desert with a combined area of about (82) Km. Drilling activities in this area were commenced in late 1980s till first oil discovery was announced by (AMOCO) in (1994), Since that; and through February 2009; a total of (4.2) MMSTB oil was produced from six wells in both fields. This paper demonstrates that an intensive review of petrophysical parameters had led to re-discovering the actual unforeseen bigger volume of the old matured fields that had been producing since decades; resulting in boosting up the combined production levels from about 600 BOPD to about 7000 BOPD while still development activities continues to prove extensions to both field and add more reserves. Subject fields are producing upper cretaceous reservoirs of both Abu Roash G (A/R_G) and Upper Bahariya (U.B.) formations; this area was formerly famous for low well productivity and non-encouraging economics; but after Sahara Oil and Gas Co. (SOG) received the operatorship of these oil leases in Feb 2009, a petrophysical interpretation review was applied to find out the reason behind more than 10 years of stable production rates, the review included investigating the validity of the formerly used models for interpreting the existing shaly sand that indicated high water saturations that never matched the production data; also, an individual well interpretation parameters were considered instead of the formerly generalized set of parameters over-all the fields. The conclusion of this paper could be summarized in attracting attention to the importance of a new eye vision when considering a new evaluation of reserves of an oil field that had been formerly considered as a matured one; while still investigating each piece of information that might have over-estimated or under-estimated the never-seen reservoir volume.
- Africa > Middle East > Egypt > Western Desert > Greater Western Dester Basin > Gindi Basin > Qarun Field (0.99)
- Africa > Middle East > Egypt > Western Desert > Greater Western Dester Basin > Abu Gharadig Basin > North Bahariya Concession > Abrar Field > Abu Roash 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)
- Reservoir Description and Dynamics > Reservoir Characterization (1.00)
- Reservoir Description and Dynamics > Reserves Evaluation > Estimates of resource in place (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
- Management > Asset and Portfolio Management > Field development optimization and planning (1.00)
Abstract Nanotechnology has become the buzz word of the decade! The precise manipulation and control of matter at dimensions of (1-100) nanometers have revolutionized many industries including the Oil and Gas industry. Its broad impact on more than one discipline is making it of increasing interest to concerned parties. The Nanotechnology applications have pierced through different Petroleum disciplines from Exploration, to Reservoir, Drilling, Completion, Production and Processing & Refinery. For instance, Nano-sensors have been developed rapidly to enhance the resolution of the subsurface imaging leading to advanced field characterization techniques. Nanotechnology also strikes the stage of production enormously to enhance the oil recovery via molecular modification and manipulate the interfacial characteristics. Moreover, in a very similar fashion, it provides novel approaches to improved post production processes. Only very few publications were able to report the latest accomplishments in different Petroleum Engineering domains. This paper provides an overview of the latest Nano-technological solutions in the O&G industry and covers the recent research developments that have been carried out around the world and paves the way for many researchers and organizations who are interested in the integration of these technological advancements, to discover the challenges and the revolution that Nanotechnology is about to bring to O&G Industry in Egypt. Egypt's domestic demand for oil is increasing rapidly. Oil consumption has grown by more than 30% in the past ten years. Also, the hydrocarbon reserves in Egypt have witnessed an average increase of 5%/year over the past seven years, while the average recovery factor is still stuck at the 35%. Nanotechnology holds the key solution to this local production challenge as it helps increase the recovered Oil and decrease the cost of production by eliminating problems that occur throughout the field development operations.
- North America > United States (1.00)
- Europe (1.00)
- Asia > Middle East (1.00)
- Africa > Middle East > Egypt (1.00)
- Geology > Rock Type > Sedimentary Rock (0.47)
- Geology > Geological Subdiscipline (0.46)
- Energy > Oil & Gas > Upstream (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (0.94)
Abstract The recent breakthrough developments of polymer-filled armor cables with crush-free electrical cores, effectively eliminate inherent limitations of wireline logging cables. These novel cables deployed with a complete high-tension conveyance package have effectively reduced deepwater-wireline tool sticking occurrences and the subsequent lengthy fishing operations in emerging Deepwater and depleting reservoirs. Unique composite polymer technology locks the normally unbound cable armors to the core. Further Coldflow and crush resistant protection is added to the cable core itself. The result is a mechanically rigid, torque-balanced and crush-free wireline cable that effectively eliminates known issues with core codlflow, cable rotation & plastic stretch, armor stranding & bird-caging, while enabling high-tension spooling on a drum without the use of tension relief system (Capstan). With spooling tensions up to 13,000 lbf, instantaneous pulls of 18,000 lbf and a safety margin of 9,000 lbf, the complete high tension package offers tool sticking mitigation capabilities only possible previously with a Capstan package. Additional benefits include but not limited to fully seasoned new cable and reduced frequency of cable maintenance. Furthermore, the elimination of the dual drum Capstan eliminates significant operational risk. TuffLINE 18000 - a composite cable was deployed successfully without Capstan in Deepwater Australia for an operation including formation pressure and sampling in a reservoir with a high tool sticking potential. In a particularly challenging situation in the Mediterranean where Capstan could not be deployed, TuffLINE 18000 was used in 5 descents resulting in 96 hrs of rig time savings while reducing HSE and operational risk. With the proven financial and HSE benefits, polymer filled composite wreline cables and the high-tension conveyance package reduce wireline tool sticking risk.
- North America > United States (1.00)
- Africa (0.94)
- North America > Cuba > Gulf of Mexico (0.89)
- Europe > United Kingdom > North Sea (0.89)
- Europe > Norway > North Sea (0.89)
- (2 more...)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
- Production and Well Operations > Well Intervention (1.00)
- Health, Safety, Environment & Sustainability (1.00)
Abstract The Arta fields of Egyptian Eastern Desert are operated by Petrodara, a joint venture of Transglobe Energy and Egyptian General Petroleum Corporation (EGPC). The main producing horizon is the Nukhul and formation pressure measurements are critical in this poorly sorted conglomerated marl in order to understand and model depletion. However, low permeability and high viscosity oils contributed to a very low mobility environment that presented considerable challenges to Wireline Formation Tester (WFT) tools. Extensive testing programs resulted in an excessive amount of tests that were unusable, being classified as ‘dry’, ‘tight’ or ‘supercharged’. This low mobility environment also complicated the requirement for PVT samples acquired with the WFT tools. Normal testing operations resulted in very high drawdowns that sampled below formation pressure and caused emulsions with the filtrate of the water based drilling fluid. In this paper we discuss how the Operator and the Service Company combined to employ fit for purpose WFT techniques to acquire accurate formation pressure data and PVT quality oil samples. Most of our discussion will be based on understanding the dynamics of pretesting in low permeability formations and how the optimal tool and pretest design can produce results where previous attempts have failed. Specifically we consider the newest ‘pretest only’ WFT that provides very fine control over pretest rate and volume and allows precise test design that is not possible with conventional WFT tools. Additionally, we demonstrate the application of best practices and lessons learned from worldwide sampling operation to acquire PVT quality heavy oil samples.
- Africa > Middle East > Egypt (1.00)
- Africa > Middle East > Djibouti > Arta > `Arta (0.27)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.69)
- Geology > Petroleum Play Type > Unconventional Play > Heavy Oil Play (0.61)
- Africa > Middle East > Egypt > South Sinai Governorate > Lagia Field > Nukhul Formation (0.99)
- Africa > Middle East > Egypt > Gulf of Suez > Gulf of Suez Basin > Rudeis Formation (0.99)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Pressure transient analysis (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
- (2 more...)
Abstract Reservoir saturation monitoring, through cased wells, usually is the main key factor for proper reservoir management and recovery optimization in the cases of developed and mature oil fields. Thermal decay time tool (TDT) has been the main technique used for monitoring the inter wells water saturations in developed reservoir. One of the main problems that encountered while using TDT log is the reservoirs with low formation water salinity, this problem may also appear in reservoirs that are supported by water injection projects, in which the formation water is diluted by the injected water. This problem has been solved by combining TDT technique and cased hole formation resistivity tool (CHFR). The ability to detect and evaluate bypassed hydrocarbon and monitor fluid movement in sandstone reservoir is a vital question to improve production and increase recovery. It is difficult to interpret the TDT data in reservoirs with low-salinity sandstone formation water. This problem cannot be solved because TDT measurements depend on the salt content in formation brine. Instead the cased hole formation resistivity tool (CHFR) is proposed to overcome the limitations associated with pulsed-neutron tools. This paper presents case studies of pay zones-saturation monitoring obtained from TDT and CHFR logs recorded in wells in mature sandstone reservoir which suffers from high water cut. The results are referenced to open-hole resistivity logs to monitor the vertical movement of reservoir fluids. It was found that water saturations calculated from CHFR logs are more accurate than TDT log in most cases. Water shut-off remedial action to manage water production from producing sections in the studied wells has been much more successful based on CHFR / TDT logs than the proposed remedial action based only on TDT data interpretation.
- North America > United States (1.00)
- Asia > Middle East > Saudi Arabia (1.00)
- Africa > Middle East > Egypt (1.00)
- (4 more...)
- North America > United States > California > San Joaquin Basin > Elk Hills Field (0.99)
- Asia > Middle East > Bahrain > Awali Field (0.99)
Abstract This paper discusses more than 30 years of experience in auditing and evaluating oil and gas fields and its value in managing risks/uncertainties around the globe. These activities are highly dependent on the quality of the data utilized, especially those of well log data, together with the techniques used in measuring the physical and the fluid properties of both the core data, the interpretation of the well logs, the pressure transient analysis, and the Pressure Volume Temperature (PVT) data of the associated reservoirs. The importance of using correct data by checking its quality has become one of the most challenging and important tools in reducing risks and uncertainties in recent years. This conclusion has been based on the fact that while auditing and evaluating oil and gas fields around the globe in the past 30 years, a vast majority of the data that I have observed has been found to be compromised. Moreover, it was also observed that while analysis was highly dependent on the quality of the data utilized, the interpretation procedures accordingly requires accurate input data (like in the case of log interpretation, pressure transient analysis or even core and PVT analysis), and these analysis were found to have serious errors on parameters involved in calculating important reservoir parameters and constructing geological models required for future reservoir development and reservoir management. Field examples to show the size of the damages created by using unchecked data quality will be exhibited in this study especially in heterogeneous reservoirs. How to accurately calculate important reservoir parameters with field examples will also be illustrated, and the effects of such techniques in reducing uncertainties by calculating oil and gas reserves will also be addressed. Summary and suggestions of ideal methods will be included in our assessment of data to better describe reservoirs, constructing better geological models, calculating oil and gas reserves and reducing risk and uncertainties; and thus, calculating accurate overall recovery factors. It may be concluded from this publication that since these techniques has been a significant factor in either enhancing or reconstructing a better and accurate geological model used in most of the studies which were carried out by the author in each field evaluation around the globe, I am highly confident that Egypt might benefit by using the same principals to better describe their reservoirs and accurately construct their geological models.
- Asia > Middle East > Oman (0.94)
- North America > United States > Texas (0.68)
- Africa > Middle East (0.67)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.49)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.31)
- Geophysics > Borehole Geophysics (1.00)
- Geophysics > Seismic Surveying > Borehole Seismic Surveying (0.46)
- Geophysics > Seismic Surveying > Surface Seismic Acquisition (0.46)
- Asia > Middle East > Oman > Ghaba Salt Basin (0.99)
- Asia > Middle East > Oman > Al Wusta Governorate > Ghaba Salt Basin > Saih Rawl Field > Miqrat Formation (0.99)
- Asia > Middle East > Oman > Al Wusta Governorate > Ghaba Salt Basin > Saih Rawl Field > Barik Formation (0.99)
- (3 more...)
Abstract In Egypt's Western Desert, water saturation evaluation of the Upper Bahariya reservoirs is complicated by significant uncertainties in the resistivity-based saturation equation inputs, mainly the formation water salinity, but also the cementation factor and the clay cation exchange capacity (CEC). A novel dielectric multifrequency measurement was able to clearly identify zones in which oil was present, regardless of these inputs. It provided a residual oil saturation and clear differentiation of oil-bearing zones from water-saturated zones. The measurement also permitted us to apply constraints to the conventional saturation interpretation from shallow and deep resistivities. This process highlighted the variability of formation water salinity across the well and the mixing of filtrate and formation waters in the zone investigated by microresistivity tools. The dielectric tool also measures dielectric dispersion, from which a parameter (MN) related to the tortuosity of the conduction path can be extracted. This MN parameter was used to refine the water saturation computation from deep-resistivity logs. Variation of the MN parameter between 1.8 and 2 was observed in the reservoir zones. In the zone of interest, a water saturation difference of 7-8 % was observed in the cleanest zone between water saturation computed using the variable MN parameter and that computed using a fixed cementation factor of 1.9. The water saturation recomputed using the data from the dielectric log matches well the irreducible water computed from the nuclear magnetic resonance (NMR) data. Dielectric dispersion was also used to derive the CEC, which was then input as a direct measure of shaliness in the deep-resistivity saturation equation. The dielectric measurement increased the accuracy of the water saturation computation in this challenging environment and provided data that are not directly available with conventional logging.
- Europe > Italy > Adriatic Sea > Adriatic Basin (0.99)
- Africa > Middle East > Egypt > Western Desert > Bahariya Formation > Upper Bahariya Formation (0.99)
A Case Study of Evaluating Reservoirs in the Malay Basin
Zulkipli, Siti Najmi (PETRONAS Carigali Sdn. Bhd.) | Kyi, Ko Ko (PETRONAS Carigali Sdn. Bhd.) | Haddad, Sammy (Schlumberger) | Johan, Zailily (Schlumberger) | Wa, Wee Wei (Schlumberger) | Sinnappu, Suresh (Schlumberger) | Lim, Lee Chin (Schlumberger)
Abstract Formation fluid type and composition are important and integral parameters in reservoir characterization and evaluation. Fluid type and composition can be obtained by capturing samples from limited depth across the producing zone. However, recent advances in downhole fluid analysis (DFA) enable the downhole fluid identification and composition measurement from depth where the fluid samples are either not collected or when PVT results are not readily available. A new wireline technology in insitu fluid analysis (IFA) was used to achieve this objective. This work is based on field data from a newly drilled well in Malay Basin where the targeted reservoirs are comprised of clastic formation on the upper section of tested interval and of Central Luconia carbonate in the bottom section. The insitu fluid analysis technology has successfully guided the identification of oil and water in the clastic formation and gas in the carbonate. The detailed information on oil and gas composition, CO2 content, and fluid density was obtained in real time. The presence of water in clastic formation identified by wireline formation tester triggered interest in more investigation. The water producing interval is located at about 100 m down dip from a nearby development well that is producing gas. Instead of initially planned full DST, decision was made to run the wireline formation testing dual packer module to perform interval pressure transient testing (IPTT) after the well had been cased. The IPTT and DFA confirmed the water section and saved significant cost on running unnecessary testing. The methodology, applications and suggested best practices are presented in this work.
- Asia > Malaysia > South China Sea (0.61)
- Asia > Malaysia > Sarawak > South China Sea (0.25)
- Asia > Malaysia > South China Sea > Malay Basin (0.99)
- North America > United States > Texas > East Texas Salt Basin > Shell Field (0.98)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Pressure transient analysis (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Formation test analysis (e.g., wireline, LWD) (1.00)
- (2 more...)