Fracture Treatment Design and Execution in Low Porosity Chalk Reservoirs

Cipolla, C.L.; Hansen, K.K.; Ginty, W.R.

doi:10.2523/86485-ms

Cited by 13 publications

(3 citation statements)

References 7 publications

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“…2). This is a chalk field of Maastrichtian and Danian age, with the reservoir structure being an elongated double‐dipping anticline with a long axis oriented NW‐SE and a graben‐like structure on the crest (Cipolla, Hansen and Ginty 2007, Fig. 3).…”

Section: Data Applicationmentioning

confidence: 99%

An estimation method for effective stress changes in a reservoir from 4D seismics data

García

MacBeth

2013

Geophysical Prospecting

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Advances in seismics acquisition and processing and the widespread use of 4D seismics have made available reliable production‐induced subsurface deformation data in the form of overburden time‐shifts. Inversion of these data is now beginning to be used as an aid to the monitoring of a reservoir's effective stress. Past solutions to this inversion problem have relied upon analytic calculations for an unrealistically simplified subsurface, which can lead to uncertainties. To enhance the accuracy of this approach, a method based on transfer functions is proposed in which the function itself is calibrated using numerically generated overburden strain deformation calculated for a small select group of reference sources. This technique proves to be a good compromise between the faster but more accurate history match of the overburden strain using a geomechanical simulator and the slower, less accurate analytic method. Synthetic tests using a coupled geomechanical and fluid flow simulator for the South Arne field confirm the efficacy of the method. Application to measured time‐shifts from observed 4D seismics indicates compartmentalization in the Tor reservoir, more heterogeneity than is currently considered in the simulation model and moderate connectivity with the overlying Ekofisk formation.

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Section: Data Applicationmentioning

confidence: 99%

An estimation method for effective stress changes in a reservoir from 4D seismics data

García

MacBeth

2013

Geophysical Prospecting

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“…8 So using the following guideline, only a small portion of all zones were perforated. Perforating all the zones will lead to the propagation of complex multiple fractures along the wellbore, and thus make the process more difficult to be controlled.…”

Section: Selection Of Perforation Intervalmentioning

confidence: 99%

Case Study: Massive hydraulic fracturing in volcanic gas, China

Weng¹,

Lei²,

Ding³

et al. 2011

SPE Production and Operations Symposium

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This paper details the design and execution of 4 massive hydraulic fracturing in low permeability volcanic reservior in NP oilfield, north China. The top burial of target gas bearing D1 range from 4317m to 4962.6m, and the intervals range from 36.8 m to 161.8 m. The porosity and permeability vary from 1.76% to 8.13% and less than 0.1×10 -3 μm 2 to 0.61×10 -3 μm 2 respectively, with average poisson's ratio and Young's modulus at 0.35 and 52800 MPa respectively. The reservoir temperature of the 4 wells are between 162℃ and 183℃, which update the highest temperature record in China fracturing history till now. Additionally, FMI results show that the natural fractures are widely distributed in the gas reservoir.According to the characteristic of the reservoir, we brought forward a systematic hydraulic fracturing technology which included: CMHPG rating of temperature 180℃ with lower concentration and lower damage, high strength ceramic proppant with different types and sizes, a new kind of mini-fracturing, a new optimization technique of fractures and treatment parameters.The total fracturing fluid and total proppant varied from 602 m 3 to 1020 m 3 and 47 m 3 to 105 m 3 . Post-analyses indicate that the density of the natural fractures determines the net pressure, and also determines whether the treatment was difficult or not.The experience can direct the treatment in the similar gas reservoir.

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“…South Arne 12,13 The South Arne field is located in the northern part of the Danish sector of the North Sea in water depth of 60 m. The installations comprise a combined wellhead, processing, and accommodation platform. The reservoir is an elongated structure, 93 km² in area, 2,800 m deep (deepest chalk in Denmark), and is comprised of high porosity/low permeability chalks from the Maastrichtian and Danian ages.…”

Section: Introductionmentioning

confidence: 99%

Horizontal Well Completion and Stimulation Techniques--A Review With Emphasis on Low-Permeability Carbonates

Rodrigues

Neumann

Torres

et al. 2007

Proceedings of Latin American &Amp; Caribbean Petroleum Engineering Conference

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fax 01-972-952-9435. AbstractThis paper presents a brief review of the available techniques in the oil and gas industry to complete and stimulate horizontal wells, with emphasis on low permeability carbonates. These techniques can also be applied in non-conventional reservoirs, particularly in tight formations. The paper starts by reviewing the lessons learned in some chalk fields in the North Sea (Dan, Halfdan, South Arne, Valhall and Eldfisk) and in a few pilot projects offshore Brazil (Congro and Enchova). Based on these lessons learned and in the broad literature, the paper devises some considerations on the methodology to select completion and stimulation techniques for horizontal wells. Cased and cemented horizontal wells, in addition to open hole and perforated/slotted liners wells are addressed. The macro aspects of field/area management are stressed as the completion and stimulation drivers. The key parameters for designing, implementing and evaluating horizontal completion and stimulation are presented, emphasizing the most common failures and the controversial aspects. The paper presents a summary of mature field and new scenarios that are candidate to horizontal completion and stimulation in Brazil and other Latin America countries. Then it makes a few comments on the resources available in Latin America to face the mentioned opportunities and related challenges. It is supposed that this brief review will be useful for the low permeability scenarios in Latin America and worldwide. Completion and Stimulation of North Sea Low-Permeability CarbonatesThe North Sea low permeability chalks are taken here as a reference due to the outstanding technological evolution verified there in the last decades. Amongst more than ten fields producing from these reservoirs in the North Sea this paper focuses on the Dan, Halfdan, South Arne, Valhall and Eldfisk fields. The main characteristics of these fields are: shallow waters (43 to 69 m), dry completion, high volumes of OOIP (1.6 to 2.9 billions barrel), low permeability carbonates (0.2 md to 10 md) with microfractures in the central areas (10 md to 120 md), high porosities (up to 48%), soft to very soft chalks, small to medium net pays (15 m to 65 m), high oil saturation (up to 97%), and light oils ( about 36 o API). What most distinguishes these fields is their over-pressured soft chalks which are subjected to a high degree of compaction under pore pressure depletion, resulting in loss of drilling fluids, rapid production decline, well failures and seafloor subsidence. On the other hand the positive effects of rock compaction as a reservoir drive energy, outweigh by far the negative ones. The recovery factor under primary recovery can be as high as 30%. In general the North Sea chalks experienced an evolution from vertical/directional wells stimulated with acid treatments to multiple fractured horizontal wells.

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Fracture Treatment Design and Execution in Low Porosity Chalk Reservoirs

Abstract: TX 75083-3836, U.S.A., fax 01-972-952-9435.

Cited by 13 publications

References 7 publications

An estimation method for effective stress changes in a reservoir from 4D seismics data

An estimation method for effective stress changes in a reservoir from 4D seismics data

Case Study: Massive hydraulic fracturing in volcanic gas, China

Horizontal Well Completion and Stimulation Techniques--A Review With Emphasis on Low-Permeability Carbonates

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