Efficient Technology Application to Optimize Deep Gas Well Completions in the Khuff and Jauf Formations Requiring Hydraulic Fracturing in Saudi Arabia

Solares, Jose Ricardo

doi:10.2118/68206-ms

Cited by 20 publications

(11 citation statements)

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“…12,26 In addition, wells treated with HCl/formic acid showed better performance than wells treated with other acid systems. 2 However, the most important issue in this study was the integrity of the super Cr-13 tubing. According to Table 1, the main elements present in the tubing besides iron are Cr, Ni, and Mo.…”

Section: Treatment Evaluationmentioning

confidence: 95%

“…Solares gave more details on well completion and the mechanical strength requirements for well tubulars for the fracture treatments. 2 Rahim and Al-Qahtani discussed the criterion used for selecting the perforation intervals. 1 The pumping schedule (Tables 5 and 6) utilizes a high temperature borate-gel to initiate a fracture in the formation, followed by alternating stages of the gelled or in-situ gelled HCl/formic acids acid and borate gel pads.…”

Section: Field Treatmentsmentioning

confidence: 99%

“…2 The reservoir has a permeability of 0.1 to 5 mD and tends to have significant porosity. 3 The non-associated gas is sour with hydrogen sulfide content that varies from 0 to 10 mol%.…”

Section: Introductionmentioning

confidence: 99%

“…This acid system is also based on HCl/formic and contains a synthetic polymer, a cross-linker, and a breaker, and other acid additives. This acid cross-links over a narrow pH range (2)(3)(4) where its viscosity increases by several order of magnitude. The objectives of this work were to: (1) Determine the advantages of using insitu gelled HCl/formic acid over gelled HCL/formic acid (2) Evaluate field application of in-situ gelled acids to stimulate deep carbonate gas reservoirs, and (3) Optimize the treatment based on lab and field results.…”

Section: Introductionmentioning

confidence: 99%

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Long-Term Comparative Evaluation of HCl/Formic Acid System Used To Stimulate Carbonate Formations at Severe Conditions in Saudi Arabia

Nasr‐El‐Din

Al-Driweesh

Sierra

et al. 2006

International Oil Conference and Exhibition in Mexico

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractThe high levels of carbon dioxide and low levels of hydrogen sulfide content of some deep and high temperature gas producers contributed in the requirement to complete these wells using super Cr-13 tubings. Due to the low permeability of the formation and the associated formation damage issues, acid fracturing treatments were required to optimize the productivity of these wells. This paper describes the selection, optimization and long term comparative evaluation of the gelled and in-situ crosslinked HCl/formic acid systems used this type of wells. The high temperatures encountered in deep wells and the susceptibility of super Cr-13 to severe corrosion in high concentration HCl systems used for stimulation purposes added one additional difficulty to the acid stimulation process. To overcome these problems, extensive experimental and field studies were performed to select an acid system to enhance the productivity of these wells.Core flood tests performed with HCl/formic acid systems showed their ability to create deep wormholes in tight carbonate cores; however the corrosiveness of these systems at downhole conditions could be severe if the correct type and concentration of corrosion inhibitor is not used. In general, for the HCl/formic acid systems at downhole conditions (275°F) it was found that high concentrations of corrosion inhibitors are required to protect the super Cr-13 completions.Based on lab tests study acid stimulations were performed, the flow back fluid was recovered and analyzed to observe the corrosion problems and to optimize the corrosion inhibitor.In all the cases the wells responded very well to the acid stimulation and the completion integrity was not compromised in a short or long term. The paper also shows for the first time a comparative long term well response to the acid stimulation of the two acid systems used in the area, showing the better performance of the in-situ crosslinked HCl/formic system over the gelled HCl/formic system.

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Section: Treatment Evaluationmentioning

confidence: 95%

Section: Field Treatmentsmentioning

confidence: 99%

“…2 The reservoir has a permeability of 0.1 to 5 mD and tends to have significant porosity. 3 The non-associated gas is sour with hydrogen sulfide content that varies from 0 to 10 mol%.…”

Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

See 2 more Smart Citations

Long-Term Comparative Evaluation of HCl/Formic Acid System Used To Stimulate Carbonate Formations at Severe Conditions in Saudi Arabia

Nasr‐El‐Din

Al-Driweesh

Sierra

et al. 2006

International Oil Conference and Exhibition in Mexico

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“…Low carbon mild steel (API 5CT L-80 and N80) was consider and for initial Khuff completion development (Cho and Al-Ajwad, 2008) but soon being replaced by low alloy C95, 13.5#/ft and for increased bottom hole treating pressure and optimize Van Top HC connections. Then, further study was completed and mild sour service T95 was selected and for targeting increased CO 2 partial pressure and Chloride content, reduce H 2 S pitting and reduce capital expenditures (Solares, 2001).…”

Section: Introductionmentioning

confidence: 99%

Iron Sulfide and Removal in Scale Formation Sour Gas Wells

et al. 2016

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Scale formation has been a persistent challenge in many sour gas wells producing from one of the world's largest gas reservoir in Saudi Arabia. Accumulation of scale deposits on downhole tubular and in wellhead manifold interferes field operation, limits well accessibility and decreases well productivity. Extensive efforts have been devoted to understand the scale formation process and to develop cost-effective mitigation strategy. This paper discusses the up-to-date knowledge on the scale formation in these prolific gas wells and presents the descaling technologies deployed and currently considered.Scale composition analyses have been performed for a large number of deposits collected during well workovers and interventions. Wide range of mineral phases were identified and their distribution showed significant variations with samples. Scale often consisted of several different mineral phases. Iron sulfides were usually the dominant components, these included pyrrhotite, troilite, mackinawite, pyrite, marcasite and greigite. Ferric iron scales, such as hematite, magnetite, akaganeite, goethite and lepidocrocite, were also common in the scale mixtures. Common mineral scales, especially calcite, were often found. In addition, iron carbonate and other ferrous iron compounds were also identified. The relative abundance of these minerals showed wide-ranging variations from well to wells. Those variations also changed and with depth and time in the given wells. A more interesting phenomenon was the layered structure in the scale deposits, with two distinct layers having very different compositions. These results provided critical information for the understanding of scaling formation process.Scale removal with chemical method had limited success in past. Scale dissolvers, based on HCl acid, caused severe tubular corrosion and formation damage. Different mechanical techniques have been tested and implemented over the years. These field experiences are reviewed in the paper. Also, challenges and requirements for scale dissolvers are discussed.

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Mineralogical, Pore and Petrophysical Characteristics of the Devonian Jauf Sandstone Reservoir, Hawiyah Field, Eastern Saudi Arabia

Saner¹,

Hassan²,

Al‐Ramadan³

et al. 2006

J Petroleum Geol

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Throughout the subsurface of the Arabian Peninsula, the approximately 460ft thick, Devonian Jauf Formation generally consists of well-compacted, low-porosity sandstones and shales, but it also includes friable and highly porous sandstones which form significant gas and condensate reservoir intervals. The mineralogy and pore properties of these reservoir intervals at the Hawiyah field (part of the giant Ghawar structure) were studied by integrating petrographic data with petrophysical measurements of reservoir sandstone samples.The reservoir sandstones are mainly composed of quartz arenites containing small amounts of altered potassium feldspar grains, authigenic illite and chlorite. Based on the pore types, which reflect the habits of the intergranular clays, three reservoir sandstone types have been defined: Type A, characterized by macroporosity; Type B, with microporosity; and Type C, with combined laminations of Types A and B. The dominance of pore-lining clay (as in Type A) or pore-filling clay (as in Type B) is the principal factor controlling the petrophysical properties of the samples. Types A and C sandstones contain macro pores, but irreducible water saturation is high (25 to 45%) compared to clean samples elsewhere, because of the presence of micropores associated with clay. In Type B sandstones the irreducible water saturation is commonly greater than 40% because all the pores spaces are in the microporosity range. The irreducible water saturation in Type B sandstones increases rapidly as porosity decreases. When porosity is less than 10%, the corresponding permeability is 0.2 mD, but no economic production can be expected because water saturation is as high as 100%. In the producing intervals, authigenic clays result in low electrical resistivity due to high water saturation; however, water-free gas is produced.

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Efficient Technology Application to Optimize Deep Gas Well Completions in the Khuff and Jauf Formations Requiring Hydraulic Fracturing in Saudi Arabia

Cited by 20 publications

References 1 publication

Long-Term Comparative Evaluation of HCl/Formic Acid System Used To Stimulate Carbonate Formations at Severe Conditions in Saudi Arabia

Long-Term Comparative Evaluation of HCl/Formic Acid System Used To Stimulate Carbonate Formations at Severe Conditions in Saudi Arabia

Iron Sulfide and Removal in Scale Formation Sour Gas Wells

Mineralogical, Pore and Petrophysical Characteristics of the Devonian Jauf Sandstone Reservoir, Hawiyah Field, Eastern Saudi Arabia

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