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Collaborating Authors
SPE/PAPG Annual Technical Conference
Abstract As more technologies to enhance oil production recovery are being developed, well stimulation has been introduced and it acts as one of the important roles to fulfil the demand of world for energy. Well stimulation is a well intervention performed on an oil or gas well to increase production by improving the flow of hydrocarbons from the drainage area into the well bore. Well stimulation generally uses fluids which create or enlarge the flow channels of formation so that it can overcome low permeability of formation. A most common and one of the most successful well stimulation is matrix acidizing. In matrix acidizing, acids are injected at matrix pressure below formation fracturing pressure. The permeability of formation will be increased either by removing the pore-plugging materials in the formation or by creating new or enlarged flow paths in the rock depending on the formation and acid types. The right type of acid or combination of acids must be used to remove the damage. Thus, careful acid choice and treatment design are critical for a successful matrix acidizing. This paper presents the results of laboratory investigation of different acid combinations: HF/HCl, HF/HCOOH, HF/H3PO4, HBF4/HCl and HBF4/HCOOH. Hydrofluoric acid and fluoboric acid are used to dissolve clays and feldspar, while hydrochloric acid, phosphoric acid and formic acid are added to control the speed of reaction to allow the maximum acid to penetrate the core sample and also act as a buffer to maintain pH of the solution. Different tests have been performed on the core samples before and after the acidizing to do the comparative study. The results analyzed are permeability, porosity, color change, strength and mineralogy. Most of the new combinations used in this research showed better results than mud acid. But overall it is clear that in coming future lot of work can be done on sandstone acidizing prospects.
- Asia > Pakistan (0.28)
- Asia > Middle East (0.28)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (1.00)
- Geology > Mineral (1.00)
Gas Hydrates in Makran: Identifying the Possible Analogies with the Reservoirs Around the World for Future Development and Exploitation
Ishaq, Samana (MOL Pakistan Oil and Gas CO.B.V.Islamabad) | Khan, Asif (Balochistan University of Information Technology, Quetta) | Hashim, Muhammad (Balochistan University of Information Technology, Quetta) | Ansari, Mubashir (Balochistan University of Information Technology, Quetta) | Khan, Safiullah (Balochistan University of Information Technology, Quetta)
Abstract Gas hydrates may be seen as a panacea for the world's current energy woes. The possibilities of developing effective and economical methods of producing gas hydrates at an economically feasible rate have quadrupled due to the latest developments in technology. The Makran coast in Pakistan provides significant geological evidence of the possible presence of oceanic hydrates (some 200m thick hydrate bearing zone along the entire offshore Makran belt have been identified through BSR surveys). This paper aims at identifying and correlating the propitious geological settings and palpable similarities of the hydrates around the world with those of Makran coast. The resulting study will help us in providing the possible methods of production and to solve those problems that may in future hinder the productive potential of the gas from these reservoirs. The correlation would help in identifying the possible future potential of producing gas, as it is being produced through hydrate dissociation in the Messoyakha gas field, Siberia. Possible challenges associated with the production from gas hydrates include environmental safety as well as drilling challenges. The correlation understudy in this paper will aim at identifying the possible solutions to these problems and will also show that many of the doubts propounded about the practicality of gas hydrate projects are mere hypothetical and literary conjectures. The exploitation of gas hydrates in Makran would not only help the country at producing cheap energy locally, but would also lead to the development of better ways of exploiting these reserves all around the world. Pakistan could also catch-up with the Hydrate Research and Development Programs of the likes of India and Japan if serious cognizance is taken of these untapped frozen gas reserves off the coast of Makran.
- North America > United States (1.00)
- Asia > Pakistan (1.00)
- Asia > Russia > Ural Federal District > Yamalo-Nenets Autonomous Okrug > Tazovksy District (0.24)
- Geology > Structural Geology > Tectonics > Plate Tectonics (1.00)
- Geology > Structural Geology > Tectonics > Compressional Tectonics (1.00)
- Geology > Geological Subdiscipline (1.00)
- (2 more...)
- Geophysics > Seismic Surveying > Seismic Processing (1.00)
- Geophysics > Seismic Surveying > Seismic Modeling > Velocity Modeling (0.68)
- Asia > Russia > Ural Federal District > Yamalo-Nenets Autonomous Okrug > Tazovksy District > West Siberian Basin > South Kara/Yamal Basin > Messoyakhskoye Field (0.99)
- Asia > India > Andhra Pradesh > Bay of Bengal > Krishna-Godavari Basin (0.99)
- Asia > Pakistan (0.93)
- Asia > Afghanistan (0.89)
Improvement of Cementing in Deep Wells
Ilyas, Muhammad (1Mari Gas Company Limited, Pakistan) | Sadiq, Nauman (2Dowell Schlumberger Western S.A., Pakistan) | Mughal, Muhammad Ali (1Mari Gas Company Limited, Pakistan) | Pardawalla, Hassan (2Dowell Schlumberger Western S.A., Pakistan) | Noor, Sameer Mustafa (2Dowell Schlumberger Western S.A., Pakistan)
ABSTRACT This research work "Improvement of Cementing in Deep Wells" was carried out with the collaboration of Mari Gas Company Limited (MGCL), Pakistan and Schlumberger Pakistan, to recommend the designs and practices by which future cementing operations for zonal isolation in deep Wells may be improved. Mari Gas Company Limited had successfully drilled, tested and completed Halini Well - 1 (Total Depth = 5350 m) in the Karak Block. The Karak Block is located in Northern Region of Pakistan which is known for its challenges, such as high pressure water influxes and weak zones, which led to a number of cementing challenges in this Well. The Cementing related problems that were faced on this Well were: 1-Sustained Casing Annulus Pressure in 13 3/8" × 9 5/8" Casing Annulus 2-Poor CBL-VDL results in 13 3/8" and 9 5/8" Casing The scope of the project was to investigate the root cause of cementing challenges faced at Halini Well-1 and to propose recommendations for improving future cementing in deep Wells. In regards to the above, the cementing of Halini Well- 1 was thoroughly analyzed along with similar case histories and problems in offset fields. On the basis of observations made, various recommendations have been proposed, mostly related to areas of fluid rheology, fluid contamination, fluid channeling, density and friction pressure hierarchy between fluids, fluid loss, temperature differential, and setting of casing slips etc. The idea for this project is to serve as a guideline for cementing the future deep Wells.
- Asia > Pakistan (1.00)
- Asia > Middle East > Saudi Arabia (0.28)
- Asia > Pakistan > Upper Indus Basin (0.99)
- Asia > Pakistan > Khyber Pakhtunkhwa > Karak District > Karak Block (0.99)
Introduction of High Pressure (HP) Separator and its Applications in Pakistan
Maqbool, Zohaib (1 Eastern Testing Services (Pvt.) Ltd) | Khattak, Kifayat (1 Eastern Testing Services (Pvt.) Ltd) | Malik, Javaid Hussain (1 Eastern Testing Services (Pvt.) Ltd) | Ahmed, Jawad (2 MOL Pakistan Oil and Gas company B.V)
Abstract Well testing is an important tool for field appraisal, field development, reservoir surveillance and management. Some key measurements during well testsareflow rates of individual phases, fluid properties, fluid composition, flowingsurface, down hole pressure and temperature etc. Analysis of this datahelps in pinpointing where improvements can be made, how the productive potential of the reservoir can be enhanced and where the future investments are to be focused. So production testing campaigns of wells are to be conducted and should be conducted annually or bi-annually to get the aforesaid vital information of the well and the reservoir. While gathering vital data during production testing, an apprehensionis that the hydrocarbon produced and separated on surface should notbe flared, as it can cause a huge financial loss and environmental harm. Therefore, a zero flaring concept was adopted during production in which the separated gas was safely and effectively injected back to the production line and the fluids to the storage facility. In Pakistan, production testing is generally carried out using conventional 1440psi separator andimplementing zero flaring concepts. But there are certain limitations associated with the conventional 1440 psi separators available in the country. A few of them are that they cannotbe used on wells whose downstream pressure or injection line pressure is greater than the safety limit of 1440 psi separator. They cannot be used on wells with high gas rates greater than the maximum limit of conventional 1440 psi separator which is 60 MMSCFD and the same limitation applies to condensate/oil/water rate as well. For this reason there are certain fields in Northern Pakistan where production testing campaigns with zero flaring cannot be carried out due to the above mentioned limitations of 1440 psi separator. This paper describes the introduction of the first ever High Pressure (HP) separator in Pakistan. This separator has overcome the limitations due to its high design pressure of 2160 psi and high gas and oil flow rate capacity which in 90 MMSCFD and 13000 bpd respectively. Successful field applications at three different fields in Pakistan are discussed in this paper covering lesson learned and best practices during the operations. Producing wells were tested without flaring or wasting any hydrocarbon which is harmful to environment. All the separated gas was injected back to the high pressure production line which resulted in a huge financial advantage. The application of the non-conventional high pressure separator and implementing zero flaring is proven to be a beneficial solution with huge potential for future applications in Pakistan.
Combating Solids Precipitation and Depostition in ADHI Gas-Condensate Process Plant
Ahmed, Shujjat (Pakistan Petroleum Limited) | Qadeer, Suhail (Pakistan Petroleum Limited) | Bouamra, Reda (Pakistan Petroleum Limited) | Chaker, Ahmed Abu (Pakistan Petroleum Limited) | Jamaiuddin, Abul (Pakistan Petroleum Limited)
ABSTRACT Adhi gas—condensate field is located near Islamabad, Pakistan. Pakistan Petroleum Limited started fluid processing and recovery of Liquefied Petroleum Gas and Condensate around in 1990. The liquid stream was processed with no solids deposition in the past. Recently, the liquid processing circuit of the plant has experienced an increasing amount of black solid deposition, which is trapped into the liquid filters located in the plant. To identify the root causes of the problem of these solids depositional systematic approach was applied including taking various solid, liquid and gas samples from the plant inlet and various locations inside the processing plant and analyzing them for diagnostics. Based on the outcome of the root-cause analysis, a chemical mitigation strategy has been developed, tested and implemented, resulting in significant reduction in problems related with solid depositions in processing plant.
- Asia > Pakistan > Balochistan > Dera Bugti District > Lower Indus Basin > Guddu Block > Sui Field (0.99)
- Asia > Pakistan > Punjab > Upper Indus Basin > Potwar Basin > Adhi Field > Chorgali-Sakesar Formation (0.98)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Gas-condensate reservoirs (1.00)
- Production and Well Operations > Well Intervention (1.00)
- Production and Well Operations > Production Chemistry, Metallurgy and Biology > Inhibition and remediation of hydrates, scale, paraffin / wax and asphaltene (1.00)
- Facilities Design, Construction and Operation > Flow Assurance > Precipitates (paraffin, asphaltenes, etc.) (1.00)
Fluid Characterization of a Retrograde Gas Condensate Reservoir for the Simulation Study
Khan, M. Noman (Pakistan Petroleum Limited, Karachi) | Bilal, Hafiz M. (NED University of Engineering & Technology, Karachi) | Shoaib, M.. (NED University of Engineering & Technology, Karachi) | Manzoor, Abdul-Ahad (NED University of Engineering & Technology, Karachi) | Shaukat, Wasif (NED University of Engineering & Technology, Karachi) | Shakil, Talha (NED University of Engineering & Technology, Karachi)
Abstract Correct selection of Equation of State (EOS) model is required for proper fluid characterization of retrograde gas condensate fluid so that PVT behavior in the simulation model can be correctly defined. This paper describes the methodology used for establishing the criteria for selecting the most representative PVT laboratory analysis when several PVT analyses are available. The steps for Equation of State (EOS) modeling from the selected PVT report of a retrograde gas condensate fluid sample, which will be used in compositional reservoir simulation model, are also presented in the paper. One of the important steps in the proposed methodology is to examine the available PVT analysis results for accuracy, consistency and validity. The Whitson Torp (K-value flash) method which is based on mass balance has been used for evaluating experimental data by calculating percentage difference between reported values and calculated values of oil composition, molecular weight of C7+ and specific gravity of C7+ at abandonment pressure. EOS models have been developed using two well- known PVT analyses software. Three parameter Peng-Robinson EOS was selected for EOS modeling. The EOS model was tuned by regressing the Binary Interaction Coefficients and other critical properties of pseudo components. After regression, the fluid composition was lumped into five components to reduce simulation time while preserving the inherent nature of the EOS model. The developed EOS model has been used for material balance and simulation studies.
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Gas-condensate reservoirs (1.00)
- Reservoir Description and Dynamics > Fluid Characterization > Phase behavior and PVT measurements (1.00)
- Reservoir Description and Dynamics > Fluid Characterization > Fluid modeling, equations of state (1.00)
ABSTRACT Asphaltene Precipitation and Deposition is a serious problem which can reduce the oil recovery by reducing reservoir permeability and altering the wettability. It can plug wells and flow lines through deposition and also cause separation difficulties at the separation facilities. Taking preventive measures are always a wise solution rather than attempting to resolve issues when they are occurred. This study proposes a strategy and provides the comprehensive review of the methodology required to predict and prevent Asphaltene Precipitation. Light crude oil samples were taken to be characterized for their thermodynamic properties. The saturation pressure and Asphaltene Onset Point (AOP) were measured at different pressures, temperatures and compositional changes using the Solid Detection System (SDS). Phase diagram and Asphaltene Precipitation Envelopes (APE) were developed. Cubic Plus Association (CPA) equation of state was used to develop the Asphaltene phase envelope using Multiflash (infochem). Titration technique was used to obtain the Asphaltene Floculation point (AFP) using the dead oil and n-Heptane as a precipitant. Effect of different inhibitors was then evaluated using the Solid Detection System (SDS) equipment using the titration technique. Rock-Inhibitor Compatibility was then checked in the reservoir core samples by performing the dynamic core flooding test in the laboratory. Conclusively, this strategy helps to enhance the reservoir performance by minimizing the asphaltene precipitation and will save the cost associated with the consequences of high asphaltene precipitation.
- Energy > Oil & Gas > Upstream (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (0.97)
- Reservoir Description and Dynamics (1.00)
- Production and Well Operations > Production Chemistry, Metallurgy and Biology > Inhibition and remediation of hydrates, scale, paraffin / wax and asphaltene (1.00)
- Facilities Design, Construction and Operation > Flow Assurance > Precipitates (paraffin, asphaltenes, etc.) (1.00)
Abstrct The explosive growth of shale gas production in the US has sparked a global race to determine which other regions from around the world have the potential to replicate this success. One of the main areas offocus is the Asia Pacific region, specifically Pakistan. In this paper, real results from seven different US shale basins-Marcellus, Eagle Ford, Haynesville, Barnett, Woodford (West-Central Oklahoma), Fayetteville and Bakken- have been used to develop a comprehensive sequence of shale exploitation strategy for emerging shale plays. The study involves integration of shale gas exploitation knowledge reinforced by a decade of experience across most of the North American shale gas basins, with published data. Different reservoir properties have been compared to develop a comprehensive logic of the effective techniques to produce from shale-gas reservoirs. We have validated the sequence with real results from US shale production ventures, published case histories, and by global experts who have been directly involved in shale reserves evaluation and production. Subsequently, several different reservoir attributes of Pakistan shale plays have been compared with US basins, in an attempt to identify analogues. It is the intent of this paper to diminish the difficult and often expensive learning cycle time associated with a commercially successful shale project, as well as to attempt to illustrate the most influential factors that determine optimum production. A very few papers in the petroleum literature that provide an extensive and systematic approach towards shale exploitation strategy for given shale-reservoir conditions
- North America > United States > Texas (0.69)
- Asia > Pakistan > Sindh (0.69)
- North America > United States > Arkansas > Washington County > Fayetteville (0.25)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > North America Government > United States Government (0.70)
Introduction of Nippleless Tubing Stop Plug Application in Pakistan
Sherwani, Waseem Akhtar (1 Eastern Testing Service (Pvt) Limited) | Qureshi, Imran (1 Eastern Testing Service (Pvt) Limited) | Khattak, Kifayatullah (1 Eastern Testing Service (Pvt) Limited) | Ali, Abdul Salam (1 Eastern Testing Service (Pvt) Limited) | Ali, Syed Dost (2 Pakistan Petroleum Limited)
Abstract Well control is the management of the hazardous effects caused by the unexpected well release. In a production well, downhole safety valve and X-mass tree are considered the main barriers against the well release in the event of a worst case scenario surface disaster. Inadequate risk management and improperly managed well control situations cause blowouts, potentially resulting in a fire hazard. This paper describes a case history of a production well where a tubing string was roded severely during production phase. The problem was detected while attempting to retrieve the separation sleeve in the long string which was not accessible at the required depth. Downhole camera indicated that 90% of the long string had been eroded and remaining 10% is connected with the flow coupling. Thus, full workover job was required to replace tubing strings. However, the lack of well control barrier in the tubing to prevent uncontrolled flow of hydrocarbons prior to blowout preventer (BOP) installation for the workover was a serious safety concern. Introduction of Nippleless Tubing-Stop Plug technology provide an effective, safe and economical remedial solution to the problem.
- Asia > Pakistan (0.88)
- North America > United States > Texas (0.29)
- North America > United States > Texas > Permian Basin > Yeso Formation (0.99)
- North America > United States > Texas > Permian Basin > Yates Formation (0.99)
- North America > United States > Texas > Permian Basin > Wolfcamp Formation (0.99)
- (21 more...)
Underbalance Drilling of an Above Sea Level, Sub-Hydrostatic Reservoir; Recompenses – A Case History
Malik, Saeed Aslam (1 Oil & Gas Development Company Limited, Pakistan) | Channa, Munsif Hussain (1 Oil & Gas Development Company Limited, Pakistan) | Majeed, Arshad (1 Oil & Gas Development Company Limited, Pakistan) | Latif, Muhammad Khalid (1 Oil & Gas Development Company Limited, Pakistan) | Asrar, Muhammad (2 Weatherford, Pakistan)
Abstract During this period of energy crisis in Pakistan every effort is being made to produce every molecule of subsurface hydrocarbons. Particularly, the gas reservoirs which were not brought on production, due to low well deliverability or lack of required technology in the past are being explored and exploited. These include Tight, Low BTU, Sour and Acidic gas reservoirs. Such reservoirs pose specific problems related to drilling, production and development aspects. This paper depicts drilling and testing of a reservoir which is above sea level and its initial reservoir pressure is approximately 1000 psi below the normal hydrostatic pressure. It is one of the lowest pressure reservoirs of the world which has been drilled with successful flow of gas. Underbalance drilling technology was chosen to drill this challenging reservoir. Primary objective of under balance Drilling (UBD) was to establish reservoir potential by acquiring virgin reservoir characteristics. Historically, three wells have been drilled to test this reservoir. First two wells were drilled using conventional drilling methodology, both the wells experienced heavy mud loses during drilling and it was difficult to evaluate the production potential of this low pressure reservoir. Afterwards, pay zone of SML in third well × #02 was drilled and tested using Underbalance Drilling technique. This paper further describes the problems faced by the operator to drill first two wells in terms of mud losses and evaluation of production potential of low pressure reservoir of SML. In conclusion, it was a successful application which happened due to exceptional team work from all project parties. This application has opened new horizons of exploration and production of such reservoirs particularly in Baluchistan and generally in Pakistan.
- Asia > Pakistan > Sindh > Central Gas Basin > Sui Main Limestone Formation (0.99)
- Asia > Pakistan > Central Gas Basin > Sui Main Limestone Formation (0.98)
- Well Drilling > Pressure Management > Underbalanced drilling (1.00)
- Well Drilling > Drilling Operations (1.00)
- Well Drilling > Drilling Fluids and Materials > Drilling fluid management & disposal (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Drillstem/well testing (1.00)