Recap and Integrated Rock Mechanics and Natural Fracture Study in the Bakken Formation, Williston Basin

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1 Recap and Integrated Rock Mechanics and Natural Fracture Study in the Bakken Formation, Williston Basin EERC, 2011 Cosima Theloy PhD Candidate Department of Geology and Geological Engineering Colorado School of Mines Dec. 2 nd, 2011 Bakken Consortium Meeting

2 Contents Introduction PART 1 Recap of completed research + Regional stress & structural control + Production data and completion design + Pore-overpressure distribution + Organic Geochemistry / HC generation potential + Reservoir facies variability PART 2 Rock-mechanical properties of reservoir facies Conclusions + Bakken versus Three Forks + Facies, texture, mineralogical composition, natural fractures Working Hypothesis & Future Work

3 Introduction Conventional fracture detection methods: FMI logs, cores, Drill Stem Tests, minifrac-tests, loss of circulation, etc. New approach: Integration and correlation of data from potential fracture formation mechanisms and comparison to changes in productivity and hydraulic fracturing performance.

4 Introduction Correlation of observations and data from various disciplines improved data coverage Highest hydrocarbon generation potential Pore- overpressure distribution Facies variations / mechanical stratigr. Regional stress / structural control Natural Fractures Completion Design Production

5 Regional Stress & Structural Control Sh max Montana Sh max North Dakota modified from Sonnenberg, 2010 Regional natural fracture trends NE-SW oriented Present-day minimum and maximum horizontal stresses of similar magnitude little anisotropy

6 Regional Stress & Structural Control Basement faults, tipping out in Prairie Salt, cause gentle folding at Bakken level Natural fractures?? Mudlogs of 6 wells searched for evidence of natural fracturing No relationship observed between deepseated faults and gas shows

7 Production Data & Completion Design

8 Production Data & Completion Design Bear Den Bear Den Technological differences in S Nesson Pore-pressure gradient reflects productivity of area

9 Production Data & Completion Design Eastern part of Sanish Field more productive than western part! Not related to technical differences Eastern Field 760% Comparison of wells with similar completion design Western Field

10 Production Data & Completion Design 789 wells 2006 to to wells 3086 wells Initial Production maps (bbl/day) of Bakken producers 1268 wells 2009 to present

11 High Productivity Areas Sweetspots based on Bakken and Three Forks IP maps Bakken Three Forks

12 Pore-overpressure BHP good 9A good BHP good 9A good NDIC fair Mean: 0.62 psi/ft SD: BHP good Mean: 0.61 psi/ft SD: NDIC DST fair poor Mean: 0.63 psi/ft SD: Mean: 0.59 psi/ft SD: 0.079

13 Pore-pressure data clean-up - variability of pressure maps depending on which data was used - quantity of bullseyes - in detail inconsistencies (e.g.: 0.65 psi/ft next to 0.74 psi/ft) CORRECTION dataset clean-up reduction from 426 to 80 data points A D OK B E PERFECT C F

14 Pore-overpressure and productivity Increasing production with increasing pore pressure Three Forks has slightly higher pore pressure than Bakken higher production with less difference in frac gradient and pore pressure

15 Hydrocarbon generation potential Original TOC Lower Bakken TOCo = HI x TOC x HIo x (1 F) x (83.33 TOC) + (HI x TOC) = 650 (Peters et al. 2005) 469 wells Original TOC Upper Bakken 582 wells USGS data

16 Original TOC and pore pressure Sum TOCo (%) Original total organic matter content of both Upper and Lower Bakken Shale Contours = pore pressure (psi/ft) Good match with high-pressure area 428 wells Eastern part likely high-pressured, but low TOCo

17 Original TOC and production Good match for bulk of highly productive areas Fields in the East do not coincide with high TOCo values 428 wells

18 Main Oil Generation Window Tmax Upper Bakken HI Upper Bakken 534 wells 594 wells Fields at eastern margin largely in main oil generation window

19 Reservoir Facies Variability S BN Sec. 15, T 146N, R 101W Big Sky 1 Sec. 2, T 30N, R 58E Harvey Gray Sec. 26, T 31N, R 54E N Lateral continuity of facies across the basin (with exception of the bench ), BUT distinct facies-internal variations in grain size and mineralogical content

20 PART 2 Rock Mechanics Study of the Reservoir Facies

21 Dataset Energy and Environmental Research Center (EERC) ISRM Type 2 testing procedure 48 samples from 20 wells in North Dakota 28 Middle Bakken samples 3 MB-F 10 MB-E 5 MB-C 6 MB-B 3 MB-A 1 Pronghorn 20 Three Forks samples 18 TF-B 2 TF-A EERC, wells in-detail analysis(7 to 8 samples each)

22 Study Area in-detail analyzed wells

23 Objective Are rock-mechanical properties (Young s Modulus, Poisson s ratio) facies-dependent? - Bakken versus Three Forks - Middle Bakken facies What effect does texture have? -laminated - bioturbated / disturbed / chaotic -massive What influence has mineralogical composition on rock properties? -dolomite -clay -silt Impact of presence / absence of natural fractures in cores?

24 Rock-mechanical properties

25 Facies

26 Brittleness Deadwood Canyon Ranch Scallion U Bakken shale Scallion U Bakken shale Middle Bakken Facies E, F D C B A Middle Bakken L Bakken shale L Bakken shale Upper Three Forks Facies B A Upper Three Forks Middle Three Forks Middle Three Forks Sonnenberg, 2011

27 Texture

28 Natural Fractures Presence / absence of natural fractures in core close to sampling depth reticulate fracture network vertical fracture

29 Mineralogical Composition Young s Modulus Similar variability in rock-mechanical properties for each component class Poisson s Ratio Mineral contents determined by visual estimation from thin sections

30 Burial Depth noticeable lower Young s Modulus in shallow samples

31 CONCLUSIONS

32 Conclusions PART 1 No evidence for natural fracturesat the flanks of the Nesson anticline due to deep-seated faults Technological advancements in completion design increase production through time, but area and pore-pressure have larger impact Cleaned-up pressure data match well with original TOC distribution and high productivity areas Fields at eastern margin of basin and Williams / McKenzie areas are currently in the main oil generation window, causing overpressure. PART 2 Rock-mechanical propertiesof Middle Bakken and Three Forks samples are variable, but show similar ranges throughout different facies, textures and mineralogical compositions

33 Working Hypothesis & Future Work

34 Role of Natural Fractures easy permeability -> induced fractures -> natural fractures matrix permeability Natural fractures probably occur everywhere in the basin where oil generation has taken place, but they are notthe discriminating factor between sweetspot and non-sweetspot areas

35 Role of Natural Fractures Tight Oil Decline Curve slope flattens out long well life expectancy dependent on matrix permeability and pressure

36 Migration & Entrapment 5 th order residual trend surface of Middle Bakken structure shows subtle bumps better Maybe an explanation for why Sanish and western McKenzie / Williams areas are so successful purple areas = fetch areas greater fetch area -> more oil migration updip trapped HCs accumulate in structural, stratigraphic or diagenetic traps not trapped HCs migrate off into Canada

37 Future Work Geochemical Data - Define oil families -Evaluate possible migration distances Productive / non-productive boundary at eastern margin - Investigate nature of boundary / trap > diagenetic, maturity? > So and Sw Update existing datasets and interpretations -Production, completion design, pore-pressure

38 Colorado School of Mines Bakken Consortium Mike Johnson Consulting Geologist

39 Acknowledgements I wish to thank Darren Schmidt (EERC) Dr. Steve Sonnenberg and my Bakken fellow students! Request to you all Please, send me your PRESSURE DATA (including build-up curves or raw data to create build-up curves) to complete the new pore-pressure map. ctheloy@mines.edu Thank you!

40 Back-up

41 Are natural fractures a key for high productivity? If yes, are they predictable? Investigated parameters: Reservoir Thickness & Quality Analysis of natural fractures in Nesson area Basinwide correlation: Identification of fracture formation mechanisms Mapping of key factors (fractured reservoir map) Completion Design + Advances in technology + Well type + No. of frac stages + Proppant & fluid characteristics Overpressure + Bottom Hole Pressure gradient + Frac gradient + Difference BHP and FG Organic Geochemistry + Original TOC + Tmax & HI (maturity) + Migration Gas Shows & Mud Weight Structure, Faults & Lineaments Prairie Salt & Pronghorn

42 Depositional Model

43 Geochemistry Data MAIN OIL GENERATION

44 Anderson Smith 1-26H MB-F MB-E MB-C laminated MB-E ft Depth (ft) MB-B MB-A LBS massive TF-B TF-A disturbed massive laminated MB-A ft Young's Modulus (10^6 psi) MB-F MB-E MB-C Depth (ft) MB-B MB-A LBS massive TF-A ft 9820 TF-B TF-A Poisson's Ratio disturbed

45 Bloom SWD 1 Depth (ft) MB-F MB-E MB-B MB-A LBS TF-B disturbed laminated disturbed disturbed MB-F ft shell layer disturbed MB-E ft Young's Modulus (10^6 psi) MB-F Depth (ft) MB-E MB-B MB-A LBS laminated TF-B ft Poisson's Ratio TF-B vertical fracture disturbed

46 EN Ruland H MB-F massive MB-F ft MB-C laminated Depth (ft) MB-B MB-A LBS TF-B massive vertical fracture disturbed massive massive MB-C ft Young's Modulus (10^6 psi) MB-F MB-C laminated Depth (ft) MB-B MB-A LBS TF-B ft TF-B Poisson's Ratio disturbed

47 Middle Bakken vs. Three Forks 6 wells have one sample each from Middle Bakken and Three Forks Middle Bakken has higher Young s Modulus (4 out of 6) Poisson s ratio ambiguous Three Forks higher dolomite content Middle Bakken higher silt and moderate dolomite content

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