FRINK Linked Data Fragments server

Matches in SemOpenAlex for { <https://semopenalex.org/work/W4253036963> ?p ?o ?g. }

• W4253036963 abstract "Gas Diffusion - Its Impact on a Horizontal HPHT Well Nigel D. Bradley; Nigel D. Bradley BP plc Search for other works by this author on: This Site Google Scholar Eric Low; Eric Low BP plc Search for other works by this author on: This Site Google Scholar Bjarne Aas; Bjarne Aas RF-Rogaland Research Search for other works by this author on: This Site Google Scholar Rolv Rommetveit; Rolv Rommetveit RF-Rogaland Research Search for other works by this author on: This Site Google Scholar Hans F. Larsen Hans F. Larsen RF-Rogaland Research Search for other works by this author on: This Site Google Scholar Paper presented at the SPE Annual Technical Conference and Exhibition, San Antonio, Texas, September 2002. Paper Number: SPE-77474-MS https://doi.org/10.2118/77474-MS Published: September 29 2002 Cite View This Citation Add to Citation Manager Share Icon Share Twitter LinkedIn Get Permissions Search Site Citation Bradley, Nigel D., Low, Eric, Aas, Bjarne, Rommetveit, Rolv, and Hans F. Larsen. Gas Diffusion - Its Impact on a Horizontal HPHT Well. Paper presented at the SPE Annual Technical Conference and Exhibition, San Antonio, Texas, September 2002. doi: https://doi.org/10.2118/77474-MS Download citation file: Ris (Zotero) Reference Manager EasyBib Bookends Mendeley Papers EndNote RefWorks BibTex Search Dropdown Menu toolbar search search input Search input auto suggest filter your search All ContentAll ProceedingsSociety of Petroleum Engineers (SPE)SPE Annual Technical Conference and Exhibition Search Advanced Search AbstractIf a HPHT well with oil based mud is left undisturbed for a period, eg. when tripping or logging, methane will diffuse from the formation through the mud invaded zone and mud filter cake into the well bore. This can amount to substantial quantities and will occur despite an overbalance of mud hydrostatic pressure existing. Consequences can be potential well control problems when circulation is resumed or pipe is tripped back into the well or degradation of mud properties including loss of weighting material or ‘baryte sag’.IntroductionIf a well, which is drilled overbalanced through a gas formation, is left without circulation for an extended period of time, gas from the formation will diffuse through the mud invaded zone and filter cake and accumulate in the drilling fluid. In the case of oil based mud at HPHT conditions, methane is infinitely soluble in the oil and substantial amounts of gas can be dissolved in the mud. The rather shallow mud invaded zone in the near well bore region created when using oil based mud will enhance the process.In this paper the rate of gas diffusion from the formation into the well bore in a 1000m long horizontal HPHT well at TVD of 4630m in the Devenick field is estimated. A description of the theory is given and the corresponding gas flow rates into the well are calculated. Some possible consequences for well control and mud properties are addressed, and issues concerning the simplifying assumptions in the theory and uncertainties in the physical parameters are discussed.Mud invaded zoneAfter the drill bit has penetrated the formation a small amount of drilling mud will invade the near well bore region. This spurt loss of drilling fluid lasts for only a few seconds [1] and stops when a filter cake of low permeability has been formed. Later, additional fluid will percolate into the formation very slowly.It is assumed that the fluid invasion consists of pure base oil. The water droplets in the drilling fluid invert emulsion will normally quickly plug the pore throats at the well bore-formation interface in a layer of effective thickness less than 0.1 mm, and do not enter into the formation. Similarly, other particles in the mud will be filtered out of the fluid invasion.The invaded zone caused by the initial mud spurt loss may have a thickness of typically 1 to 5 cm, depending on the formation properties [1]. After this initial period, the pressure differential across the well bore-formation interface will be applied upon the water droplets in the mud filter cake. Further fluid loss proceeds very slowly. A typical invasion velocity may be around 1 cm per 24 hours [1]. This effect is ignored in the estimates below.With excessive overbalance of mud hydrostatic in the well or unfavourable formation properties, the water droplets in the drilling fluid invert emulsion may fail to plug the pore throats at the well bore-formation interface adequately. The fluid invasion may then continue until particles and polymers in the mud manage to build the filter cake sufficiently and partly stop the filtrate loss. In this case the invasion zone will be much deeper and the gas diffusion from the formation into the well bore correspondingly slower. For as long as an appreciable rate of fluid invasion continues, gas diffusion counter to the invading fluid will be negligible [2]. The case with an effectively functioning water droplet drilling fluid filter cake constitutes a worst case, giving the shallowest drilling fluid invaded zone and the highest gas diffusion rate. Keywords: diffuse, upstream oil & gas, drilling fluids and materials, drilling fluid chemistry, spe 77474, diffusion, methane, porosity, drilling fluid property, concentration Subjects: Drilling Operations, Drilling Fluids and Materials, Directional drilling, Drilling fluid selection and formulation (chemistry, properties), Drilling fluid management & disposal This content is only available via PDF. 2002. Society of Petroleum Engineers You can access this article if you purchase or spend a download." @default.
• W4253036963 created "2022-05-12" @default.
• W4253036963 creator A5010607707 @default.
• W4253036963 creator A5049292058 @default.
• W4253036963 creator A5063796289 @default.
• W4253036963 creator A5069893708 @default.
• W4253036963 creator A5072177178 @default.
• W4253036963 date "2002-09-01" @default.
• W4253036963 modified "2023-09-27" @default.
• W4253036963 title "Gas Diffusion - Its Impact on a Horizontal HPHT Well" @default.
• W4253036963 doi "https://doi.org/10.2523/77474-ms" @default.
• W4253036963 hasPublicationYear "2002" @default.
• W4253036963 type Work @default.
• W4253036963 citedByCount "0" @default.
• W4253036963 crossrefType "proceedings-article" @default.
• W4253036963 hasAuthorship W4253036963A5010607707 @default.
• W4253036963 hasAuthorship W4253036963A5049292058 @default.
• W4253036963 hasAuthorship W4253036963A5063796289 @default.
• W4253036963 hasAuthorship W4253036963A5069893708 @default.
• W4253036963 hasAuthorship W4253036963A5072177178 @default.
• W4253036963 hasConcept C136764020 @default.
• W4253036963 hasConcept C161191863 @default.
• W4253036963 hasConcept C23123220 @default.
• W4253036963 hasConcept C2778805511 @default.
• W4253036963 hasConcept C37531588 @default.
• W4253036963 hasConcept C41008148 @default.
• W4253036963 hasConcept C52119013 @default.
• W4253036963 hasConcept C95457728 @default.
• W4253036963 hasConceptScore W4253036963C136764020 @default.
• W4253036963 hasConceptScore W4253036963C161191863 @default.
• W4253036963 hasConceptScore W4253036963C23123220 @default.
• W4253036963 hasConceptScore W4253036963C2778805511 @default.
• W4253036963 hasConceptScore W4253036963C37531588 @default.
• W4253036963 hasConceptScore W4253036963C41008148 @default.
• W4253036963 hasConceptScore W4253036963C52119013 @default.
• W4253036963 hasConceptScore W4253036963C95457728 @default.
• W4253036963 hasLocation W42530369631 @default.
• W4253036963 hasOpenAccess W4253036963 @default.
• W4253036963 hasPrimaryLocation W42530369631 @default.
• W4253036963 hasRelatedWork W140869909 @default.
• W4253036963 hasRelatedWork W2086064646 @default.
• W4253036963 hasRelatedWork W2115485936 @default.
• W4253036963 hasRelatedWork W2119135658 @default.
• W4253036963 hasRelatedWork W2357241418 @default.
• W4253036963 hasRelatedWork W2737632833 @default.
• W4253036963 hasRelatedWork W2748952813 @default.
• W4253036963 hasRelatedWork W2903608945 @default.
• W4253036963 hasRelatedWork W2906403665 @default.
• W4253036963 hasRelatedWork W3083202704 @default.
• W4253036963 isParatext "false" @default.
• W4253036963 isRetracted "false" @default.
• W4253036963 workType "article" @default.