Well Performance and Completion Effectiveness in the Baldy Butte Field, Washakie Basin, Wyoming

Cramer, Dave; Stallings, Darrick

doi:10.2118/49046-ms

Cited by 12 publications

(7 citation statements)

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“…Possible reasons for the discrepancy are limitations of fracture models 9 , limitations of the RPI model, and liquid loading of the fracture. 7 Due to the large volumes of produced water encountered, liquids in the fracture may play a significant role in the reduced effective fracture half-lengths calculated in RPI. The liquid loading may be caused by a stable liquid column present in the wellbore and extending into the fracture limiting flow capacity and effective half-length.…”

Section: Resultsmentioning

confidence: 99%

“…RPI is a single layer, single phase simulator that utilizes a combined mass flow rate. Lithology and petrophysical characteristics vary in the J Sand reservoir however, this method has been used successfully to determine well performance in multi-layer, variable-porosity cases as demonstrated by Cramer, et al 7 Reservoir and fracture parameters were then determined for evaluation. Only wells located in the study area ( Figure 9) were included and wells with short production histories or in which only monthly production data was available were excluded from the study.…”

Section: Rpimentioning

confidence: 99%

See 1 more Smart Citation

Well Performance in a Previously Condemned Prospect: The J-Sand Formation in the Northeast Wattenberg Field

Khachatrian¹,

Trippett²

2003

Proceedings of SPE Annual Technical Conference and Exhibition

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractThe J Sand formation is a main pay zone in the extensively developed Wattenberg field of Colorado. Until recently, operators deemed the reservoir in the northeast part of this field uneconomical due to significant production of formation water in this low permeability and sub-pressured gas zone. By modifying the conventional completion techniques of the J-Sand, an operator relatively new to the area has been able to economically exploit this reservoir. Key factors that have contributed to the success include improvements in stimulation design and production techniques. Typically, hydraulic fracture stimulation treatments for the J-Sand utilize a low viscosity, guar based, zirconium crosslinked fluid pumped at injection rates up to 24 bbl/min. The above operator differs in stimulation design by incorporating a higher viscosity, low polymer carboxy methyl guar fluid pumped at a relatively low injection rate (e.g. 12 bbl/min). Well performance evaluations utilizing the Reciprocal Productivity Index (RPI) production analysis method in conjunction with log analysis quantify stimulation effectiveness. Treatment pressure history matching with 3D fracture simulators also identify advantages in achieved fracture geometry and proppant placement with the modified treatment design.

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Section: Resultsmentioning

confidence: 99%

Section: Rpimentioning

confidence: 99%

Well Performance in a Previously Condemned Prospect: The J-Sand Formation in the Northeast Wattenberg Field

Khachatrian¹,

Trippett²

2003

Proceedings of SPE Annual Technical Conference and Exhibition

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“…RPI is a single-layer, single-phase graphical production analysis method used to analyze reservoir and fracture properties (Crafton 1997;Cramer and Stallings 1998). It combines gas, oil, and water rates into one mass flow rate for analysis.…”

Section: Refracture Casesmentioning

confidence: 99%

“…casing and consisted of 1,785 barrels of 26 pounds of gellant/1000 gallons crosslinked processed enhanced guar (PEG) based borate fluid system and 151,615 pounds of 18/40 mesh Versaprop. As compared to other guar borate systems, the PEG system allows for a lower polymer loading to be used to achieve a given level of viscosity (Cramer et al 1998). The average surface injection rate was 38 bpm and the average injection pressure was 3,679 psi.…”

Section: Refracture Casesmentioning

confidence: 99%

Awakening an Old Field—A Case Study of a Refracturing Program in the Greater Green River Basin

Shaefer¹

2008

SPE Production &Amp; Operations

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Summary Restimulation of wells completed in the Frontier Formation, a low-permeability (e.g., 0.01-0.05 md) gas sand, has proved to be successful in the Fontenelle Field. The field is east of the Fontenelle reservoir, on the LaBarge Platform in the western part of the Greater Green River Basin in southwestern Wyoming. In this area the majority of hydrocarbon reserves in the Second Frontier are produced from the massive shoreface sandstones locally known as the Second Bench of the Second Frontier (Kf22b). To date, Berco Resources, LLC has increased reserves in the Fontenelle Field by restimulating four wells producing from the Frontier Formation with massive hydraulic fracturing treatments. Because of the success of these treatments, another operator in an offset area to the north has also successfully implemented a Frontier refracturing program. This paper summarizes the refracturing program and the success which Berco Resources, LLC has realized. The candidate selection process is examined, as well as operational considerations when restimulating old wells. The stimulation treatments and fluid systems are also investigated. Daily/monthly production data consisting of gas, condensate, and water rates along with well head pressures are evaluated for all cases with fractured well type curves, the pseudoradial flow specialty plot (?p/q vs. log t), and a production simulator comparing actual versus modeled production rates. Finally, the impact of the refracturing treatments on economic return is presented. The success of the refracture treatments has led to a new drilling/completion program in the Fontenelle Field in 2006 by an operator that recently acquired the Berco Resources, LLC properties. Introduction Field Description. Fontenelle Field is approximately 75 miles northwest of the town of Rock Springs, Wyoming (Fig. 1), on the southeast end of the LaBarge Platform. The field, positioned primarily in T26N-R112W, T25N-R111W, and T25N-R112W, encompasses nearly 120 square miles in both Lincoln and Sweetwater counties. To date, production from the Fontenelle Field has been 271.77 Bcf gas and 525,563 barrels of oil from 343 wells. Production has come mainly from the Second Frontier, but thin marine sandstones in the overlying Baxter Formation have produced locally. Geology. Deposition of the Cretaceous Second Frontier Formation, in the Fontenelle area, began as lower delta plain muds, carbonaceous shales, coals, and fluvial sands prograded over the poorly developed Third Frontier shoreface facies, which represented the culmination of the Mowry transgression. Sixty to seventy feet of lower delta plain sediment was deposited before a relative rise in sea level flooded the lower delta plain environment. This resulted in an abrupt change from the lower delta plain mudstones, siltstones, and shales to offshore marine mudstones and siltstones. This transgression marked the beginning of deposition of a thick, wave dominated shoreface sequence which prograded eastward into the Cretaceous Interior Seaway and contains the majority of the gas reserves in this part of the LaBarge Platform. This shoreface sequence is known as the Second Bench of the Second Frontier (Kf22b). Gas production in the Fontenelle area comes primarily from the Second Bench of the Second Frontier (Kf22b). This shoreface sequence consists of a 30 to 60 foot thick section that grades upwards from a very fine grained, bioturbated sandstone to a more winnowed, medium grained sandstone. The top of the bench often contains a very clean, high resistivity sandstone that varies in thickness from zero to 20 feet. This is interpreted to be a clean, medium grained sandstone deposited by distributary channels that have cut into the underlying shoreface section. Permeability in these channels is generally an order of magnitude better than the underlying shoreface section. The thick shoreface sandstone is capped by the mudstones and carbonaceous shales of the lower delta plain environment. The Frontier Formation, in the Fontenelle area, conformably overlies the marine Mowry Formation and is conformably overlain by the marine Baxter Formation (Robertson and Broadhead 1993). It is Cretaceous in age and extends from upper Cenomanian to upper Turonian.

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“…A performance study of 29 wells was conducted in 1998 and the results were chronicalled in paper SPE 49046. 24 For each well, wireline log analysis was used to assign a net pay value and hydrocarbon porosityheight product (øh) and the RPI method of production analysis was used to attempt derivation of the permeability-height product (kh), permeability (k) , effective fracture half-length (X F ) and gas-in-place (drainage area). One of the most notable findings in the paper was that the economic dominance of Company A was attributable to achieving significantly greater effective X F per well than Companies B and C, even though Company A used less fracturing fluid and proppant in their treatments (see Figure 12).…”

Section: Case Study #2mentioning

confidence: 99%

Evaluating Well Performance and Completion Effectiveness in Hydraulically Fractured Low-Permeability Gas Wells

Cramer¹

2003

SPE Annual Technical Conference and Exhibition

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractHydraulic fracture stimulation often dictates the economic outcome of wells completed in low permeability gas reservoirs. Attempting to understand well performance -the rate and pressure behavior of a well over its productive lifeprovides the opportunity to discover the elements driving stimulation and completion effectiveness.This paper demonstrates the integrated use of practical reservoir engineering methods to evaluate well performance, identify flow regimes and distinguish between reservoir and completion induced behavior in low-permeability hydraulically fractured gas wells.

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Well Performance and Completion Effectiveness in the Baldy Butte Field, Washakie Basin, Wyoming

Cited by 12 publications

References 0 publications

Well Performance in a Previously Condemned Prospect: The J-Sand Formation in the Northeast Wattenberg Field

Well Performance in a Previously Condemned Prospect: The J-Sand Formation in the Northeast Wattenberg Field

Awakening an Old Field—A Case Study of a Refracturing Program in the Greater Green River Basin

Evaluating Well Performance and Completion Effectiveness in Hydraulically Fractured Low-Permeability Gas Wells

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