• Became responsible for newly acquired acreage (Loving, Ward Counties) immediately following Titus Energy acquisition. • Collaborated with multi-disciplinary team to build Harmony HNM models for active wells and evaluate full-field development strategies on accelerated timeline. Secured financial approval for Huff Doback, Brennan Dale developments.• Built type curves for 1BSS, 2BSS, 3BSS, WCXY/A, WCB, WCC, WCD using limited early-time production data from Titus wells, public… Show more • Became responsible for newly acquired acreage (Loving, Ward Counties) immediately following Titus Energy acquisition. • Collaborated with multi-disciplinary team to build Harmony HNM models for active wells and evaluate full-field development strategies on accelerated timeline. Secured financial approval for Huff Doback, Brennan Dale developments.• Built type curves for 1BSS, 2BSS, 3BSS, WCXY/A, WCB, WCC, WCD using limited early-time production data from Titus wells, public analogue performance, and machine learning approach. Ran spacing & completion size sensitivities.• Working to optimize Delaware Basin workflows by integrating some aspects of Southern Midland Basin workflows below. Show less

• Became responsible for newly acquired acreage (Loving, Ward Counties) immediately following Titus Energy acquisition. • Collaborated with multi-disciplinary team to build Harmony HNM models for active wells and evaluate full-field development strategies on accelerated timeline. Secured financial approval for Huff Doback, Brennan Dale developments.• Built type curves for 1BSS, 2BSS, 3BSS, WCXY/A, WCB, WCC, WCD using limited early-time production data from Titus wells, public… Show more • Became responsible for newly acquired acreage (Loving, Ward Counties) immediately following Titus Energy acquisition. • Collaborated with multi-disciplinary team to build Harmony HNM models for active wells and evaluate full-field development strategies on accelerated timeline. Secured financial approval for Huff Doback, Brennan Dale developments.• Built type curves for 1BSS, 2BSS, 3BSS, WCXY/A, WCB, WCC, WCD using limited early-time production data from Titus wells, public analogue performance, and machine learning approach. Ran spacing & completion size sensitivities.• Working to optimize Delaware Basin workflows by integrating some aspects of Southern Midland Basin workflows below. Show less

• Collaborated with multi-disciplinary team to optimize full-field development in Benedum Wolfcamp A, B, and C (Upton County). Major changes: loosened well spacing (4X-6X), extended lateral length (2.0-3.0 Miles), increased frac size (2,100-3,400 lbpf), and optimized landing zones. Secured financial approval for Tomahawk, Polaris, Sidewinder, and Hellfire developments.• Utilized analogues, competitive intelligence data, and Skynet (APA neural network) to create type curves using hybrid… Show more • Collaborated with multi-disciplinary team to optimize full-field development in Benedum Wolfcamp A, B, and C (Upton County). Major changes: loosened well spacing (4X-6X), extended lateral length (2.0-3.0 Miles), increased frac size (2,100-3,400 lbpf), and optimized landing zones. Secured financial approval for Tomahawk, Polaris, Sidewinder, and Hellfire developments.• Utilized analogues, competitive intelligence data, and Skynet (APA neural network) to create type curves using hybrid numerical models in Harmony. Type curves were provided to planning for use in 3-year plan and SMB NAV.• History matched LFP and OOIP using RTA workflow (SPE 205844) and updated Outlook forecasts monthly. Created Outlook Spotfire tool utilized by the RE function to visualize, QC, and track forecasts.• Merged in-house and public data (IHS, Enverus, Frac Focus) to train neural network using 1-year cumulative oil across Midland basin (R2=0.60). Variables include lateral length, completion size, geologic parameters, and engineered variables such as 4-quadrant sum spacing, horizontal depletion factor, & vertical footage perforated in-zone.• Leveraged low commodity pricing in 2020 to design and execute interference tests to quantify inter-bench and intra-bench communication. Presented analysis and conclusions to executive management including CEO.• Monitored hydraulic fracturing operations in real time using offset pressure gauges, instantaneous shut-in pressures, and open wellhead pressures. Attempted to understand fracture geometry (SPE 184865) and optimize frac design on the fly.• Created multi-linear regression IPR tool informed by Harmony HNM cases, LFPs, and Spotfire information-links to identify opportunities to deepen lifting-point. Tool maintains evergreen list of optimization candidates ranked by PIR. Show less

• Calculated spacing degradation factors using empirical and conceptual methods; evaluated full-field development strategies to optimize economics without sacrificing recovery; identified potential for 11.4% increase in PV10.• Correlated depletion factor (URTeC 1061) with 1-year oil cum in the Powell field; applied correlation to potential infill locations in order to evaluate economic feasibility of infill drilling program.• Created Spotfire tool to calculate NGL yield, gas shrink, BTU… Show more • Calculated spacing degradation factors using empirical and conceptual methods; evaluated full-field development strategies to optimize economics without sacrificing recovery; identified potential for 11.4% increase in PV10.• Correlated depletion factor (URTeC 1061) with 1-year oil cum in the Powell field; applied correlation to potential infill locations in order to evaluate economic feasibility of infill drilling program.• Created Spotfire tool to calculate NGL yield, gas shrink, BTU factor, transportation costs, & price differentials by field to be used in ARIES and Enersight; compared the historical values to assumptions provided by marketing. Show less

• Created a workflow to integrate exploration forecasting (PetroVR) into Egypt Region best-estimate forecast• Conducted water breakthrough analysis for the Ptah AEB-3E formation using petrophysical data, Chan plots (SPE 30775), and normalized WOR vs. cum; identified channeling as the predominant water production mechanism.• Utilized 3DSL FloodOpt to evaluate the Heba 200 Upper Bahariya formation waterflood (550 BOPD, 9.9 MBWPD, 14.8 MBWIPD); provided recommendations to Cairo which could… Show more • Created a workflow to integrate exploration forecasting (PetroVR) into Egypt Region best-estimate forecast• Conducted water breakthrough analysis for the Ptah AEB-3E formation using petrophysical data, Chan plots (SPE 30775), and normalized WOR vs. cum; identified channeling as the predominant water production mechanism.• Utilized 3DSL FloodOpt to evaluate the Heba 200 Upper Bahariya formation waterflood (550 BOPD, 9.9 MBWPD, 14.8 MBWIPD); provided recommendations to Cairo which could produce 35 BOPD (6%) uplift. Show less

• Created Spotfire tool to calculate & update price differential correlations in ARIES lookup table; added $218MM PV10, 4.2 net MMBOE.• Developed type curves to be booked as PUDs in Dixieland field by utilizing David Fulford’s transient hyperbolic model (SPE 174784) and Bayesian priors derived from analogue study; added $84.1MM PV10, 11.7 net MMBOE.

• Took over engineering responsibilities for Anadarko Basin foreman area (269 wells, 615 BOPD, 31.7 MMCFPD, $1.65MM/month LLI / 49% flowing, 34% plunger, 16% gas lift, 1% rod pump).• Completed 27 projects (gross cost: $1.44MM, BFIT PV10: $10.5MM, uplift above trend: 60 BOPD & 1.4 MMCFPD).• Evaluated economic and technical feasibility of installing plunger lift automation throughout the region (618 plunger lifted wells); at production uplift of 5%, project would result in BFIT PV10 of… Show more • Took over engineering responsibilities for Anadarko Basin foreman area (269 wells, 615 BOPD, 31.7 MMCFPD, $1.65MM/month LLI / 49% flowing, 34% plunger, 16% gas lift, 1% rod pump).• Completed 27 projects (gross cost: $1.44MM, BFIT PV10: $10.5MM, uplift above trend: 60 BOPD & 1.4 MMCFPD).• Evaluated economic and technical feasibility of installing plunger lift automation throughout the region (618 plunger lifted wells); at production uplift of 5%, project would result in BFIT PV10 of $5.33MM. Show less

Gained experience as foreman (hydraulic fracturing jobs, workovers, other field operations), lease operator (two routes: 255 BOPD, 9.6 MMCFPD, $675M/month LLI), measurement & automation tech (calibrated orifice meters, monitored pipeline discrepancies, coded & installed automation, maintained equipment), & roustabout (field maintenance)

• Collaborated with Dr. Anand Nagoo (UT Austin) to test the capabilities and limitations of Pipe Fractional Flow software in modeling multi-phase flow through horizontal wellbores; studied the effect of toe-up vs. toe down orientation, lateral undulations, and accumulation of fill on production; presented conclusions to management

• Lease operator (5 weeks): became familiar with surface operations, well troubleshooting, & facility optimization• Fluid technician (2 weeks): shot and analyzed fluid levels; utilized Rodstar to design rod strings and optimize production; fixed and adjusted pump-off controllers to increase efficiency• Assistant foreman (5 weeks): became familiar with downhole operations; oversaw pulling unit crews & consultants