Orchard Petroleum Engineering Solutions, PLLC (OPeS) was a professional production engineering consulting company providing production operating companies with solutions in the following areas of expertise. • Safe and environmentally sound implementation of all work• Prospect development via participation on multi-disciplinary teams• Reservoir Engineering• Artificial lift design, optimization and troubleshooting• Artificial lift root cause failure analysis (RCFA) • Production optimization pressure transient analysis• Injection and water disposal well management• Operations management, optimization & oversite• Cost cutting implementation• Frac and refracture design and implementation • Operations Workover Design and Implementation • Well testing / pressure transient analysis• Leadership and mentoring Committee member of the 11-12 April 2017 SPE/ICoTA Refrac workshop in Austin, Texas. http://www.spe.org/events/en/2017/workshop/17jaus/homepage.html OPeS is associated with:SIGMA3 Integrated Reservoir Solutions, Inc. - DenverQRI (Quantum Reservoir Impact) – Houston / ColombiaAstute Global Infoservice Company - New YorkMaha Energy - Calgary / Wyoming / BrazilCC Energy Development Ltd. - OmanGerson Lehrman Group, Inc. - New YorkCandour Energy Ltd - LondonFracWell, LLC - DenverEagle Innovations Inc. - Utah

Team Leader of engineers and technicians who managed the Colorado DJ Basin oil and gas production from legacy vertical and horizontal well Niobrara program. Duties included managing capital budget, optimizing production through best management practices of artificial lift, economic evaluations for STEM/P&A program and well work. • Responsible for production engineering management of over 2800 vertical and 490 horizontal wells producing 63 MBOEPD (63% of total field production).• Cut LOE by 40% while breaking field production records in October 2015.• Company subject matter expert for horizontal well refracturing. Developed novel horizontal well refracture technique for sleeve completions which was implemented successfully. • Company subject matter expert for artificial lift. Created gas lift training class which to date has been presented to over 100 company Operations personnel. • Implemented XSPOC program to manage all company beam pump wells.• Implemented use of gas injection in offset projection wells to limit frac hits from adjacent well frac treatments. • Member of the Noble recruiting team at Colorado School of Mines 2015. • Committee member of the SPE/ICoTA Refrac workshop held in San Antonio in September 2015. http://www.spe.org/events/15jsa2/

Worked special projects in the Colorado DJ Basin on the Prospect Development team.Worked special projects including: • Completed study and made recommendations on the continued development of the Cummins Area of the field.• Studied and made innovative plan to drill extra-long horizontal laterals (2.5 to 3 mile).• Key team member of the field wide Well Testing and Allocation task force.

Team leader responsible for delivery of surveillance and optimization program for production and service wells, pad production and central facilities, supporting liquids gathering and water disposal. Team managed production well maintenance, facilities maintenance /improvement and integrity management of wells and facilities. Seventeen direct reports include both Denver and Pinedale based staff.• Developed and implemented life cycle surveillance strategies for both wells and facilities.• Lead infrastructure improvements to reduce sales line pressure and to provide electrical power.• Managed wellbore deliquification projects which are extremely important to maximize ultimate recovery of Pinedale wells• Continued responsibilities shown below.

Production Engineering lead responsible for Pinedale gas field surveillance and for all production engineering support for Shell’s Rockies Liquid Rich Shale Exploration plays. • Provided technical leadership for well production optimization, well surveillance, artificial lift design and troubleshooting in both areas. • Provided mentoring for engineers on the team. Interface with facilities, completions and drilling teams on facility and well design. • Proposed and implemented new JetVac cleanout technology of SWAN LRS wells. • Set up several best practices meetings with co-owner company personnel. • Rockies focal point - Shell Upstream America Unconventionals artificial lift team.• Travel to field frequently to work with field personal and oversee operations.

Managed production, horizontal well completion operations and teams of Denver office and field based personnel. Optimize production and workovers on 100 wells in the Williston and 330 wells in the San Juan basins. Justified and implemented gas and water pipelines in both basins to lower cost and improve economics of plays. Recruited key people for both field & office positions. • No major safety or environment incidents. • Improved field - office communications in both basins.• 100% compliance with all regulatory requirements of NDIC and COGCC. Williston basin:• Increased operated production from 4000 to 9000 BOPD.• Reduced horizontal well completion cycle time from 120 to 40 days. • Reduced horizontal completion cost and improved productivity by organizing and implementing best practices process. San Juan basin:• Eliminated 3rd party disposal of “clean water” by implementing higher MAIP on company owned disposal wells.• Implemented low cost surfactant/solvent treatments to improve production.• Worked to lower beam pumping failures. Current yearly average 0.12 failures/well/year on over 240 wells. • Completed well reviews of all wells in field; actions implemented.

Provided engineering support for half of the 2300 wells in Monument Butte, Ouray Valley, Horseshoe Bend and Gusher fields in the Uinta Basin of Utah. Responsibilities included: maximizing the financial impact of producing and water injection wells producing 11 MBOPD and injecting 22 M BWPD. Optimized over 800 beam pump wells. Managed major expense projects and budget of over $11 MM net in 2011 to meet production targets. Recurring LOE budgeting of over $60 MM net for 2011. Budgeted and managed recurring LOE to within 1% of 2009 $36 MM net and 2% of 2010 $45 MM net.• Initiated Lufkin SAM well manager and Theta XSPOC automation project. - Justified trial and full project for Uinta Basin fields. - Placed over 475 wells on system at cost of over $7.5MM. - All new wells and selected repeat failure wells were fitted with equipment to maximize production and reduce failures. • Portable Well Test Separator project. Researched, justified, conducted HAZOP/What if? process, redesigned changes and sourced a portable well test separator for the MB field. The portable has been in operation since August 2009. Ordered two more units for delivery in May 2011.• Initiate HAZOP/What if? process for NFX.• Initiated discussions and justified dedicated onsite Root Cause Failure Analyst and Chemical Engineer in the MB field to reduce failure rates and thus reduce repair and maintenance costs.• Implemented field trial for variable speed drives for beam pump wells, hydraulic pumping units and HF variable slippage pumps to reduce failure rates. • Conducted recent tender process for sucker rods which resulted in new vendor, savings of $250M per year and eliminated internal warehousing and handling. • Member of NFX Corporate recruiting team - Colorado School of Mines fall 2010.

Supervisor of 26 engineers based in Muscat and Mukhaizna field. Responsibilities included: maximizing the financial impact of all producing, water disposal, observation and steam injection wells in the Mukhaizna field producing 23 MBOPD and injecting 41 M BBL steam per day. Completed all wells. Optimized artificial lift types (ESP, RDPCP, ESPCP, Beam Pump) to meet production targets. Worked with the Operations, Drilling and Facility teams on operating requirements for new installations which were designed to increase field production to 150 MBOPD and 550 M BBL steam per day by 2012.• Co-winner of the 2007 OXY Chuck Schwab Award. This award recognizes demonstrated excellence in leveraging knowledge gained from the annual OXY Technology Conference into “value” for OXY Oil and Gas. Title: Two OXY Steamflood Projects Mukhaizna and Wilmington – Sharing Technology, Lessons Learned and Best Practices. • Selected as one of the “first 20” people in the organization with nearly 1000 at time of departure.• Prepared, negotiated and finalized initial handover documentation between prior operator of field (Petroleum Development Oman) and Occidental before takeover of the field.• Completion Engineering department was incorporated in team in early 2008. Tendered, executed and managed completion equipment and services contracts worth over $250 MM USD.• Secured first workover rig for OXY in the Mukhaizna field.• Increased field production from 8 MBOPD to above noted levels.• Recruited entire team with home countries: Oman, Nigeria, China, Holland, Canada, Peru, Indonesia, India and USA.

Supervised diverse team of four engineers and three wireline supervisors. Responsibilities included: maximizing the financial impact of all producing / injecting resources in the Idd El Shargi North Dome and Idd El Shargi South Dome fields producing 120 MBOPD and injecting 300 MBWPD, supervision of the field wireline operations, gas lift and ESP well optimization to meet production targets, work with the Development Team on operating requirements for new installations and modification to existing systems, Production Engineering related technical analysis and proposals for production optimization, coordination with the entire OPQL Team to meet OPQL goals, budgeting and manpower requirements.• Excellent safety record for challenging offshore wireline operations on many small and large platforms.• Initiated detailed nodal analysis model for well and flowline systems optimization for the field which came onto production in the 1960's and thus had many production challenges. Staggered development projects have made bottleneck plentiful.• Team members home countries: Iraq, Pakistan, Peru, Scotland and USA.

Lead operations engineer worked a $50 million redevelopment of the 24-year-old MBB waterflood in five square mile area with 160 production and injection wells producing nearly 4 MBOPD. Responsibilities included: production and waterflood surveillance, fracture design and implementation, new well completion and workover design and implementation, well maintenance, waterflood profile management, gas lift and rod pump design and troubleshooting.• Designed fracture stimulation and completion of "eastern" Elk Hills exploration wells in 2001. • Identified candidates for stimulation and other well work. Justify work, write AFE and programs. • Directed 24 hour/day rig and non-rig operations. Supervised execution of all key well work.• MBB team lead frac engineer on field wide fracture improvement team. • Lead author for SPE paper 76723 "Fracture Stimulation Optimization in the Redevelopment of a Mature Waterflood, Elk Hills Field, California" presented first at SPE WRM in Anchorage May 2002 and again for Denver SPE meeting October 2002.• Member of Occidental Corporate recruiting team - Colorado School of Mines fall 2002.• In the early ID program for future managers.

Managed maximum profitable oil rate and reserve recovery from drill site with 53 wells that produced 43 MBOPD and injected 164 MBWPD. Optimized waterflood and gravity drainage recovery mechanisms to ultimately recover 500 mmstb from the field.• Lead multi-disciplined team that drilled one coiled tubing drilled (CTD) and five conventional wells at a cost of $26MM. • Performed well and reservoir surveillance, identified, justified and designed well work.

Managed daily production and strategic reservoir engineering on several drill sites. Duties included waterflood management, black oil simulation to select optimum injection wells conversion of new wells, pressure transient analysis, decline curve analysis, production logging, gas lift design and troubleshooting, scale inhibition treatment and monitoring. • Directed 24 hour/day well operations; identified candidates for stimulation and other well work while working 7 day on/7 day off schedule.• Lead multi-disciplinary team that evaluated and designed four new infill wells drilled at a cost of $7.2 mm. These wells added 4200 BOPD.• Representative on field wide team managing water injection and production optimization. Implemented water alternating gas injection project costing $12 MM.• Trained new and transferred engineers and engineering technicians. Member of ARCO College recruiting team to Colorado School of Mines fall 1996.• Identified, designed and implemented ten hydraulic fracture jobs. One job established three field records. Completed fracture study that prompted field-wide design change to smaller more conductive tip screen-out fractures.• Responsible for start-up of a new drill site with production of 8000 bopd including horizontal well. Designed and implemented all well work.• Received ARCO company-wide award in the "Stamp-out-waste" program for an innovative field drill site pit de-watering project. This process was safer, less expensive and stimulated the injection wells when pit water was pumped down hole during the spring break-up.