The post entitled Reservoir Development’s 2007 Restimulation Survey - Part I summarized the responses to the first three survey questions, and those responses suggested the productivity increase following restimulation is highly variable with about 1/3 of the respondents reporting essentially no increase in production following restimulation and about 1/3 of the respondents reporting greater than 100% increase in production following restimulation. The results from Question 3 offered some insight as to why results are so variable, that is, when “Intuition” is the 2nd leading method for selecting restimulation candidates over all other available diagnostic techniques, shouldn’t variability be expected? Intuition certainly isn’t quantitative: intuition can’t quantify existing stimulation effectiveness, and intuition can’t quantitatively predict the production increase following restimulation. However, several diagnostic techniques can quantify stimulation effectiveness and allow production increase following restimulation to be predicted, which means not wasting money on wells that will not benefit from restimulation.
Continuing the survey discussion, the results of questions 4, 5, 6, and 7 are as follows.
“In wells which are restimulated, what problem(s) was identified for remediation (select all that apply)?”
Fig. 2 shows that the most commonly treated problems, as indicated by 56% of the respondents, are “Bypassed pay” and “Short effective fracture half-length.” It’s also interesting that 2 respondents honestly admitted that they didn’t know the problem being remediated by restimulation.
Reservoir Development’s technology and services were developed to correctly diagnose problems that can be effectively remediated by restimulation. Not all wells are restimulation candidates, and Reservoir Development’s Refracture-Candidate IDs methodology helps operating companies prevent unnecessary restimulation treatments when incremental reserves don’t justify the expense.
Fig. 2. Problems identified for remediation by restimulation. (Click to enlarge)
“What barriers exist to a successful restimulation program (select all that apply)?”
The most common barriers existing to a successful restimulation program, as indicated by more than 50% of the respondents in Fig. 3, include “Time and manpower-for candidate selection,” “Efficient restimulation diagnostic methods,” “Wellbore condition-open perforations across multiple zones,” and “Risk.”
Reservoir Development’s technology and services address each of the four most common barriers. Reservoir Development provides the manpower and software for candidate selection, efficient diagnostics for problem identification, isolated-layer testing and stimulation to minimize the problems of multiple open perforations, and with Reservoir Development’s diagnostics, the benefit of stimulation can be quantified thereby risk can be evaluated.
Fig. 3. Barriers existing for a successful restimulation program (click to enlarge).
The remaining questions in the survey were generally specific to refracturing/restimulation in wells producing from multiple layers. The intent of the questions was to determine the understanding of the unique problems in identifying, diagnosing, and stimulating (IDs) wells producing from multiple layers, and to estimate the market potential for a technology and service company specializing in restimulation-candidate identification, diagnosis, and stimulation.
“In wells which produce from multiple layers, what percentage of targeted pay zones are bypassed or ineffectively stimulated during the original stimulation?”
Twenty-four percent of the respondents indicated that less than 10% of the targeted pay zones are bypassed and 24% of the respondents indicated that more than 30% of the targeted pay zones are bypassed. Overall, 76% of the respondents indicated that greater than 10% of the targeted pay is bypassed or ineffectively stimulated.
Bypassing greater than 10% of the targeted pay is a significant quantity of gas that is either not being produced or is inefficiently producing. Increasing the recovery of a “typical” well with an estimated ultimate recovery of 1 bcf (billion cubic feet) by 0.1 bcf may not seem significant, but over 1000 wells in a field, it represents another 100 bcf of reserves. Reservoir Development’s research shows that up to 30% of layers targeted for fracturing in wells producing from multiple layers are either bypassed or ineffectively stimulated. Reservoir Development’s technology and services can identify, diagnose, and stimulate (IDs) bypassed layers to increase estimated ultimate recovery in mature wells.
“Limited-entry fracture treatments are often the standard design in multilayer tight-gas wells. What percentage of targeted tight-gas zones are bypassed or ineffectively stimulated using limited-entry fracture treatment designs?
The most common technique for stimulating multiple layers with a single fracture treatment is limited-entry fracturing. Sixty percent of the respondents indicated that greater than 10% of the layers targeted for stimulation are bypassed or ineffectively stimulated by limited-entry fracturing techniques.
Reservoir Development’s research shows that several hundred limited-entry fracture treatments were pumped each week in the United States Rocky Mountain region. Evidence from radioactive tracer studies, microseismic mapping, and production logging strongly suggests that 10% to 30% of the layers targeted with limited-entry fracture treatment designs are bypassed or ineffectively stimulated. Consequently, during the “boom” of 2007, several hundred additional wells were added each week to the thousands of candidates for Reservoir Development’s Restimulation-Candidate IDs methodology.
Presenting Reservoir Development’s 2007 restimulation survey will continue in Part III. Please send comments or suggestions to David.Craig@resdevcorp.com.
DrBubba, aka Dr. David P. Craig, in addition to owning Reservoir Development Consulting is also an employee of Halliburton. Consequently, Halliburton requires that DrBubba post the following disclaimer:
The information on this site is mine and does not necessarily represent Halliburton's position, strategy, or opinion.
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